Text

Final Written Examination and Operating Test Outlines (Folder 3)
	ML20328A162
Person / Time
Site:	Ginna
Issue date:	09/17/2020
From:	; Exelon Generation Co
To:	; Operations Branch I
Shared Package
ML19309E375	List: IR 05000244/2020301; ML20267A420; ML20321A279; ML20322A350; ML20328A162; ML20328A279; ML20328A291; ML20329A141; ML20329A181; ML20329A200; ML20329A223; ML20329A239; ML20329A354; ML20329A432; ML20329A442; ML22103A223;
References
	CAC 000500
	Download: ML20328A162 (48)
	v • d • e

ES-301 Administrative Topics Outline Form ES-301-1 (Rev_090820)

Facility: Ginna Date of Examination: 10/2020 Examination Level: RO Operating Test Number: N20-1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.5 (2.9) Ability to use procedures related to shift Conduct of Operations staffing, such as minimum crew complement, overtime limitations, etc.

D, P, R JPM: Determine the Allowable Hours an Operator Can Work 2.1.25 (3.9) Ability to interpret reference materials, Conduct of Operations such as graphs, curves, tables, etc.

N, R JPM: Complete Plant System Checks Inside Control Room (Verify SDM) 2.2.41 (3.5) Ability to obtain and interpret station Equipment Control electrical and mechanical drawings.

N, R JPM: Determine Leak Isolation Boundaries 2.3.5 (2.9) Ability to use radiation monitoring Radiation Control systems, such as fixed radiation monitors and alarms, portable survey instruments, D, R personnel monitoring equipment, etc.

JPM: Evaluate Steam Generator Tube Leakage from R-47 Reading NOTE: All items (5 total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

Type Codes & Criteria: (C)ontrol room, (0) (S)imulator, (0) or Class(R)oom (4)

(D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes) (2)

(N)ew or (M)odified from bank (> 1) (2)

(P)revious 2 exams ( 1; randomly selected) (1)

NUREG-1021, Revision 11

ES-301 Administrative Topics Outline Form ES-301-1 (Rev_090820)

RO Admin JPM Summary A1a This is a Bank JPM. The operator will be given a previous work history, a report to work time and a time that they assumed the watch. The operator will be directed to determine the latest time that they can be relieved without violating Work Hour Rules or requiring a waiver or exception; and assuming that they get relieved and leave the site at the time determined, determine the earliest time that they can next report to work and assume the watch without violating any Work Hour Rules or requiring a waiver or exception. The operator will be expected to determine these dates and times in accordance with LS-AA-119 per the attached KEY. This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

A1b This is a new JPM. The operator will be told that they have just relieved the watch on day shift, given a set of plant parameters that places the plant in Mode 3 with RCS Temperature at 530F at a specific time in life and told that they are performing Attachment 1, Modes 1, 2 and 3 of O-6.13, DAILY SURVEILLANCE LOG. The operator will be directed to (1) Complete the Attachment 1 check to Verify SDM on Page 6 of 10, (2)

Identify all required Technical Specification ACTION and Completion Time, if any, based on the check and (3) Identify the latest time that the Shutdown Margin Check of O-6.13, Attachment 1, can be completed. The operator will be expected to determine that adequate SDM does not exist, that the required ACTION is to Initiate boration to restore SDM to within limit within 15 minutes and identify that Attachment 1 of O-6.13 must be complete by 0900 per the attached KEY.

A2 This is a new JPM. The operator will be told that a leak has occurred in the Service Water System and that the crew has entered AP-SW.1, SERVICE WATER LEAK. The operator will be directed to (1) identify the closest leak isolation boundary valves for this leak, (2) identify which, if any, of these valves need to be re-positioned from their current position, and (3) identify the Breaker location for any electrically operated leak isolation boundary valve that may need to be operated. The operator will review the Piping & Instrumentation Diagram of the Service Water System as well as system procedures and determine the closest leak isolation boundary valves for this leak, the boundary valves that need to be re-positioned and identify the Breaker location for the two MOVs in accordance with the Attached KEY.

A3 This is a Bank JPM. The operator will be told that the plant is operating at 100% power, that the crew has been notified that RMS-R47, R-47 AIR EJECTOR NOBLE GAS MONITOR, has alarmed in the TSC, provided with current readings, and told that the crew is evaluating the need to enter AP-SG.1, Steam Generator Tube Leak. The operator will be directed to determine (1) if the R-47 alarm setpoint is set properly, (2) the estimated Steam Generator Tube Leakrate based on the local R-47 reading and (3) if AP-SG.1, Steam Generator Tube Leak, should be entered based on the known information. The operator will be expected to determine that the R-47 alarm setpoints are set lower than identified by P-9, that the leakrate is 4.5 gpd based on the R-47 reading and that this leakrate is below the entry conditions into AP-SG.1.

NUREG-1021, Revision 11

ES-301 Administrative Topics Outline Form ES-301-1 (Rev_090820)

Facility: Ginna Date of Examination: 10/2020 Examination Level: SRO Operating Test Number: N20-1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.25 (4.2) Ability to interpret reference materials, Conduct of Operations such as graphs, curves, tables, etc.

M, R JPM: Determine Time to Boil for a Loss of Shutdown Cooling 2.1.18 (3.8) Ability to make accurate, clear, concise Conduct of Operations logs, records, status boards, and reports.

N, R JPM: Determine Reportability Requirements 2.2.42 (4.6) Ability to recognize system parameters Equipment Control that are entry-level conditions for M, R Technical Specifications JPM: A-52.12, Inoperability of a Fire Damper 2.3.6 (3.8) Ability to approve release permits.

Radiation Control D, P, R JPM: Review and Approve Gas Decay Tank Release Permit 2.4.38 (4.4) Ability to take actions called for in the Emergency facility emergency plan, including Procedures/Plan supporting or acting as emergency coordinator if required.

N, R JPM: Determine if Emergency Dose Limits and Thyroid Blocking Agents (Potassium Iodide [KI]) Should be Approved for Use NOTE: All items (5 total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

Type Codes & Criteria: (C)ontrol room, (0) (S)imulator, (0) or Class(R)oom (5)

(D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes) (1)

(N)ew or (M)odified from bank (> 1) (4)

(P)revious 2 exams ( 1; randomly selected) (1)

NUREG-1021, Revision 11

ES-301 Administrative Topics Outline Form ES-301-1 (Rev_090820)

SRO Admin JPM Summary A1a This is a modified Bank JPM. The operator will be provided with two sets of shutdown conditions; one current, and one projected to exist within ten days. The operator will be directed to determine the Time to Boil given a Loss of RHR for each of the two sets of conditions. The operator will be expected to use IP-OUT-2 and determine that the Time to Boil for the present plant conditions is 3.6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and for the projected conditions ten days from now is 1.65 hours7.523148e-4 days 0.0181 hours 1.074735e-4 weeks 2.47325e-5 months .

A1b This is a new JPM. The operator will be provided with a set of plant conditions that ultimately led to an automatic reactor trip from 100% power. The operator will be directed to determine reportability requirements, including completion of any necessary paperwork.

The operator will be expected to identify that this issue requires a 4-hour notification to the NRC in accordance with LS-AA-1020 (Reportability Tables and Decision Trees), and complete NRC Form 361 (Reactor Plant Event Notification Worksheet) in accordance with the provided Key.

A2 This is a modified Bank JPM. The operator will be told that the plant is operating at 100%

power and that a report from the field has indicated that Fire Damper BA-28, located in the wall separating the Turbine Building from Battery Room A, has been determined to be Non-Functional. The operator will be directed to document the failure of the Fire Damper as required by A-52.12, Nonfunctional Equipment Important to Safety; and identify all, if any, required ACTION. The operator will be expected to complete an A-52.12-F-03 in accordance with the KEY provided and identify that ACTION A.1.1 or A.1.2.1 and A.1.2.2; and A.2 of TRM 3.7.5 must be taken.

A3 This is a Bank JPM. The operator will be given a set of initial data on the D Gas Decay Tank, the current time and date and told that the on-shift Chemistry Technician has initiated a release for the D Gas Decay Tank and brought the Gaseous Waste Release Form (Attachment 1) from CH-703, RELEASE OF GDTS AND OTHER GASEOUS BATCH RELEASES, to the Control Room. The operator will be directed to review and approve the release permit for the D Gas Decay Tank and review the release permit for approval authorization and document the results on the Cue Sheet. The operator will be expected to review the release permit for Gas Decay Tank D and identify the following deficiencies: (1) Chemistry Supervision signature should be signed, (2) R-14 Alarm listed setpoint is incorrect, (3) R-14 Alarm actual setpoint is incorrect, and (4) the release has to be started within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months vice 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The operator will NOT sign to approve the release. This JPM appeared on the 2019 Initial License Exam and was randomly selected for the 2020 Exam.

A4 This is a new JPM. The operator will be given a set of emergency conditions at Ginna, told that a General Emergency has been declared, that they are the Shift Emergency Director and that they are implementing EP-AA-112-100-F-01, SHIFT EMERGENCY DIRECTOR CHECKLIST. The operator will be directed to determine if Emergency Exposure Limits need to be approved for the rescue individuals, determine if the use of Thyroid Blocking Agents must be recommended for the rescue individuals, and if so, identify recommended dosage and duration; and to prepare any paperwork that needs to be completed. The operator will be expected to determine that the rescuers need to be approved to receive Emergency Exposure Limits > 5 REM TEDE and the Thyroid Blocking Agent must be recommended such that one (1) 130 mg KI tablet (or (2) 65 mg KI tablets)

NUREG-1021, Revision 11

ES-301 Administrative Topics Outline Form ES-301-1 (Rev_090820) is issued to each rescuer per day for 10 consecutive days or until directed that the risk no longer exists; and prepare an EP-AA-113-F-02 for each rescuer and EP-AA-113-F-03 per the attached KEY.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_090920)

Facility: Ginna Date of Examination: 10/2020 Exam Level (circle one): RO Operating Test No.: N20-1 Control Room Systems@ (8 for RO; 7 for SRO-I; 2 or 3 for SRO-U)

Type Code* Safety System / JPM Title Function 004 Chemical and Volume Control System [004 A4.07 (3.9/3.7)]

A.

S, P, D, A, L 1 Borate for one rod not fully inserted following trip per ES-0.1 B. 008 Component Cooling Water [008 A2.01 (3.3\3.6)]

Initiating a Plant Heatup on RHR w/Subsequent Failure of CCW Pump S, N, A, L 8 006 Emergency Core Cooling System [006 A1.13 (3.5/3.7)]

C.

S, D, EN 2 Makeup to the B Accumulator from the RWST EPE 074 Inadequate Core Cooling (074 EA1.05 (3.9 / 4.1)]

D. S, P, D, A, L, 4P Vent RCS for Accumulator/RHR Injection EN E. 045 Main Turbine Generator System [045 A2.17 (2.7*/2.9*)]

S, D, A 4S Synchronize Generator On-Line with Improper Load Pickup F. EPE E14 High Containment Pressure [EPE E14 EA1.1 (3.7/3.7)]

S, M, L, EN 5 Verify Containment Isolation and Heat Removal 062 A. C. Electrical Distribution [062 A4.01 (3.3/3.1)]

G.

S, N 6 Establish 100/0 Electric Lineup on Circuit 767 H. 010 Pressurizer Pressure Control System [010 A4.01 (3.7/3.5)]

S, N 3 Depressurize the RCS During a SGTR In-Plant Systems:* 3 for RO; 3 for SRO-I; 3 or 2 for SRO-U I. 071 Waste Gas Disposal System [071 A3.03 (3.6/3.8)]

P, D, R, A 9 Release D Gas Decay Tank J. E04 LOCA Outside Containment [E04 EA2.2 (3.6/4.2)]

D, R, E 3 Perform SFP-RWST Attachment K. 061 Auxiliary Feedwater System [061 K4.13 (2.7/2.9)]

D, E 4S Align Self-Cooling to the TDAFW Pump

All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions, all five SRO-U systems must serve different safety functions, and in-plant systems and functions may overlap those tested in the control room.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_090920)

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 (5)

(C)ontrol room (D)irect from bank 9 (7)

(E)mergency or abnormal in-plant 1 (2)

(EN)gineered Safety Feature 1 (3) (Control Room System)

(L)ow-Power / Shutdown 1 (4)

(N)ew or (M)odified from bank including 1(A) 2 (4)

(P)revious 2 exams 3 (3) (Randomly Selected)

(R)CA 1 (2)

(S)imulator JPM Summary JPM A This is a Bank JPM. The operator will be told that the plant has experienced a reactor trip and that the crew has completed ES-0.1, REACTOR TRIP RESPONSE, through step 3.

After being told that another operator will handle all other MCB operations and alarms not associated with the assigned task, the operator will be directed to perform Step 4 of ES-0.1 (Verify MRPI Indicates - ALL CONTROL AND SHUTDOWN RODS ON BOTTOM).

The operator will be expected to determine that one control rod has not fully inserted in accordance with Step 4 of ES-0.1 and attempt to initiate boration via the normal method.

When it is discovered that boration cannot be started in accordance with step 4 RNO of ES-0.1 (Alternate Path), the operator will initiate RCS boration in accordance with ER-CVCS.1, Section 6.2.1. This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

JPM B This is a new JPM. The operator will be told that the plant is in Mode 5, that the crew has completed Section 6.5 of O-1.1, PLANT HEATUP FROM COLD SHUTDOWN TO HOT SHUTDOWN, the current RCS heatup rate is 13F/hour that Chemistry has completed all required RCS sampling and has added Hydrazine and that another operator is standing by to monitor and plot heatup rate. The operator will be directed to initiate an RCS heatup at maximum rate not to exceed 50°F/Hour with a maximum RHR System Total Flow of 1500 gpm by performing steps 6.6.1 through 6.6.3 Section 6.6 of O-1.1. The operator will be expected to raise the RCS heatup rate in accordance with section 6.6 of O-1.1 to between 20-50F/hour, and then respond to a loss of CCW by attempting to start the B CCW Pump and stopping the RCPs prior to Motor Bearing Temperature reaching 266F when this fails in accordance with AP-CCW.3 (Alternate Path).

JPM C This is a Bank JPM. The operator will be told that AR-C-4, ACCUMULATOR 1B (LOOP A) LEVEL 60 % 75, has alarmed. The operator will be directed to refill the B Accumulator to 69% using the C SI Pump. The operator will be expected to start the C SI Pump and raise the level of the B Accumulator to 69% in accordance with Section 6.2 of S-16.13, RWST WATER MAKEUP TO THE ACCUMULATORS, without the B Accumulator Level rising to greater than 75%.

JPM D This is a Bank JPM. The operator will be told that the plant has experienced a LOCA, that due to other malfunctions with the ARVs and the Safety Injection system the ability to adequately cool the core has been lost, that the crew has initiated FR-C.1, RESPONSE TO INADEQUATE CORE COOLING, that initial attempts to restore core cooling per the NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_090920) procedure have been ineffective and that Bus 15 tripped during the initial transient. The operator will be directed to continue the actions of FR-C.1 beginning at Step 23 (Check if RCPs should be started). The operator will be expected to attempt to establish Instrument Air to the Containment and when this fails (Alternate Path), use ATT-12.0, ATTACHMENT N2 PORVS, to vent the RCS using both PORVs and the Reactor Vessel Head Vent Valves. This JPM appeared on the 2019 Initial License Exam and was randomly selected for the 2020 Exam.

JPM E This is a Bank JPM. The operator will be told that the generator is being started following a refueling outage, that the generator is at 1800 rpm and the turbine is fully warmed up, and that the generator output voltage is 19 KV. The operator will be directed to synchronize the generator on-line per O-1.2, PLANT STARTUP FROM HOT SHUTDOWN TO FULL LOAD, steps 6.13.1 through 6.13.11.7. During this action, the operator will recognize that Automatic Load Pickup feature of the Turbine Control System has failed (Alternate Path). The operator will be expected to synchronize the Main Generator to the Electrical Grid, and when it is recognized that the Automatic Load Pickup has failed to function, the operator will manually load the Turbine to 40 to 60 MW, without reverse powering the Main Generator.

JPM F This is a modified Bank JPM. The operator will be told that the plant tripped from 100%

power and safety injection has actuated, that the crew entered E-0, Reactor Trip or Safety Injection, and then transitioned to E-2, Faulted Steam Generator Isolation, and that due to a degrading transient, an Orange Path now exists on the Containment Critical Safety Function Status Tree. The operator will be directed to perform FR-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE, starting at Step 1. The operator will be expected to establish Containment Spray flow including flow from the Sodium Hydroxide Tank from at least one train of Containment Spray and manually start the C CNMT Recirculation Fan Cooler.

JPM G This is a new JPM. The operator will be told that the plant is operating at 100% power, that the Electric Plant is currently in a 50/50 NORMAL lineup, and that RG&E ECC has requested that the plant be placed in a 100/0 lineup on Circuit 767 for scheduled maintenance on offsite Circuit 7T later today. The operator will be directed to establish a 100/0 Electric Plant alignment and de-energize the 12A Station Aux Transformer per O-6.9.2, ESTABLISHING AND/OR TRANSFERRING OFFSITE POWER TO BUS 12A / BUS 12B, Section 6.3. The operator will be expected to transfer 4160V buses from a 50/50 NORMAL Lineup to 100/0 Lineup on Circuit 767 and de-energize the 12A Station Aux Transformer per Section 6.3.2 and 6.3.3 of O-6.9.2.

JPM H This is a new JPM. The operator will be told that the plant has experienced a Steam Generator Tube Rupture, that the crew has completed E-3, Steam Generator Tube Rupture, through Step 17, and that the crew is ready to commence RCS cooldown. The operator will be directed to depressurize the RCS to minimize break flow and refill the Pressurizer starting with Step 18. The operator will be expected to depressurize the RCS using maximum Pressurizer Spray and terminate the depressurization once one of the four criteria listed in E-3, Step 18.b, are met.

JPM I This is a Bank JPM. The operator will be told that the D Gas Decay Tank (GDT) is full and approved for release, that the D GDT does NOT have elevated activity and the contents are not from VCT gas and that Procedure S-4.2.5, Release of Gas Decay Tank, NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_090920) is in progress with the procedure signed off through Section 5.0. After being told that the Extra EO has removed the required tagout and completed the necessary paperwork, the operator will be directed to release the D GDT in accordance with S-4.2.5, Release of Gas Decay Tank. The operator will be expected to lineup and release the D GDT in accordance with S-4.2.5, Section 6.4 and then stop the release in accordance with S-4.2.5, Step 4.2 upon an alarm condition on R-14 (Alternate Path). This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

JPM J This is a Bank JPM. The operator will be told that the plant has experienced a LOCA outside of Containment, which cannot be isolated; and that the crew has entered ECA-1.1, Loss of Coolant Recirculation. The operator will be directed to transfer water from SFP to the RWST using Attachment ATT-18.0, SFP-RWST, bypassing the SFP DI and Filter. The operator will be expected to initiate a transfer of water between the Spent Fuel Pool and the RWST bypassing the SFP DI and Filter in accordance with ATT-18.0.

JPM K This is a Bank JPM. The operator will be told that there has been a loss of the 480V safeguards buses, the crew is currently in ECA-0.0, Loss of All AC Power and the TDAFW has been running for one and a half hours with fire water not available. The operator will be directed to align self-cooling to the TDAFW pump per ATT-5.2, ALTERNATE COOLING TO TDAFW PUMP, Part B. The operator will be expected to align self-cooling to the TDAFW pump in accordance with ATT-5.2, ATTACHMENT ALTERNATE COOLING TO TDAFW PUMP within 30 minutes. This is a Time Critical JPM.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

Facility: Ginna Date of Examination: 10/2020 Exam Level (circle one): SRO(I) Operating Test No.: N20-1 Control Room Systems@ (8 for RO; 7 for SRO-I; 2 or 3 for SRO-U)

Type Code* Safety System / JPM Title Function 004 Chemical and Volume Control System [004 A4.07 (3.9/3.7)]

A.

S, P, D, A, L 1 Borate for one rod not fully inserted following trip per ES-0.1 B. 008 Component Cooling Water [008 A2.01 (3.3\3.6)]

Initiating a Plant Heatup on RHR w/Subsequent Failure of CCW Pump S, N, A, L 8 006 Emergency Core Cooling System [006 A1.13 (3.5/3.7)]

C.

S, D, EN 2 Makeup to the B Accumulator from the RWST EPE 074 Inadequate Core Cooling (074 EA1.05 (3.9 / 4.1)]

D. S, P, D, A, L, 4P Vent RCS for Accumulator/RHR Injection EN E. 045 Main Turbine Generator System [045 A2.17 (2.7*/2.9*)]

S, D, A 4S Synchronize Generator On-Line with Improper Load Pickup F. EPE E14 High Containment Pressure [EPE E14 EA1.1 (3.7/3.7)]

S, M, L, EN 5 Verify Containment Isolation and Heat Removal 062 A. C. Electrical Distribution [062 A4.01 (3.3/3.1)]

G.

S, N 6 Establish 100/0 Electric Lineup on Circuit 767 H. NA In-Plant Systems:* 3 for RO; 3 for SRO-I; 3 or 2 for SRO-U I. 071 Waste Gas Disposal System [071 A3.03 (3.6/3.8)]

P, D, R, A 9 Release D Gas Decay Tank J. E04 LOCA Outside Containment [E04 EA2.2 (3.6/4.2)]

D, R, E 3 Perform SFP-RWST Attachment K. 061 Auxiliary Feedwater System [061 K4.13 (2.7/2.9)]

D, E 4S Align Self-Cooling to the TDAFW Pump

All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions, all five SRO-U systems must serve different safety functions, and in-plant systems and functions may overlap those tested in the control room.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 (5)

(C)ontrol room (D)irect from bank 8 (7)

(E)mergency or abnormal in-plant 1 (2)

(EN)gineered Safety Feature 1 (3) (Control Room System)

(L)ow-Power / Shutdown 1 (4)

(N)ew or (M)odified from bank including 1(A) 2 (3)

(P)revious 2 exams 3 (3) (Randomly Selected)

(R)CA 1 (2)

(S)imulator JPM Summary JPM A This is a Bank JPM. The operator will be told that the plant has experienced a reactor trip and that the crew has completed ES-0.1, REACTOR TRIP RESPONSE, through step 3.

After being told that another operator will handle all other MCB operations and alarms not associated with the assigned task, the operator will be directed to perform Step 4 of ES-0.1 (Verify MRPI Indicates - ALL CONTROL AND SHUTDOWN RODS ON BOTTOM).

The operator will be expected to determine that one control rod has not fully inserted in accordance with Step 4 of ES-0.1 and attempt to initiate boration via the normal method.

When it is discovered that boration cannot be started in accordance with step 4 RNO of ES-0.1 (Alternate Path), the operator will initiate RCS boration in accordance with ER-CVCS.1, Section 6.2.1. This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

JPM B This is a new JPM. The operator will be told that the plant is in Mode 5, that the crew has completed Section 6.5 of O-1.1, PLANT HEATUP FROM COLD SHUTDOWN TO HOT SHUTDOWN, the current RCS heatup rate is 13F/hour that Chemistry has completed all required RCS sampling and has added Hydrazine and that another operator is standing by to monitor and plot heatup rate. The operator will be directed to initiate an RCS heatup at maximum rate not to exceed 50°F/Hour with a maximum RHR System Total Flow of 1500 gpm by performing steps 6.6.1 through 6.6.3 Section 6.6 of O-1.1. The operator will be expected to raise the RCS heatup rate in accordance with section 6.6 of O-1.1 to between 20-50F/hour, and then respond to a loss of CCW by attempting to start the B CCW Pump and stopping the RCPs prior to Motor Bearing Temperature reaching 266F when this fails in accordance with AP-CCW.3 (Alternate Path).

JPM C This is a Bank JPM. The operator will be told that AR-C-4, ACCUMULATOR 1B (LOOP A) LEVEL 60 % 75, has alarmed. The operator will be directed to refill the B Accumulator to 69% using the C SI Pump. The operator will be expected to start the C SI Pump and raise the level of the B Accumulator to 69% in accordance with Section 6.2 of S-16.13, RWST WATER MAKEUP TO THE ACCUMULATORS, without the B Accumulator Level rising to greater than 75%.

JPM D This is a Bank JPM. The operator will be told that the plant has experienced a LOCA, that due to other malfunctions with the ARVs and the Safety Injection system the ability to adequately cool the core has been lost, that the crew has initiated FR-C.1, RESPONSE TO INADEQUATE CORE COOLING, that initial attempts to restore core cooling per the NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020) procedure have been ineffective and that Bus 15 tripped during the initial transient. The operator will be directed to continue the actions of FR-C.1 beginning at Step 23 (Check if RCPs should be started). The operator will be expected to attempt to establish Instrument Air to the Containment and when this fails (Alternate Path), use ATT-12.0, ATTACHMENT N2 PORVS, to vent the RCS using both PORVs and the Reactor Vessel Head Vent Valves. This JPM appeared on the 2019 Initial License Exam and was randomly selected for the 2020 Exam.

JPM E This is a Bank JPM. The operator will be told that the generator is being started following a refueling outage, that the generator is at 1800 rpm and the turbine is fully warmed up, and that the generator output voltage is 19 KV. The operator will be directed to synchronize the generator on-line per O-1.2, PLANT STARTUP FROM HOT SHUTDOWN TO FULL LOAD, steps 6.13.1 through 6.13.11.7. During this action, the operator will recognize that Automatic Load Pickup feature of the Turbine Control System has failed (Alternate Path). The operator will be expected to synchronize the Main Generator to the Electrical Grid, and when it is recognized that the Automatic Load Pickup has failed to function, the operator will manually load the Turbine to 40 to 60 MW, without reverse powering the Main Generator.

JPM F This is a modified Bank JPM. The operator will be told that the plant tripped from 100%

power and safety injection has actuated, that the crew entered E-0, Reactor Trip or Safety Injection, and then transitioned to E-2, Faulted Steam Generator Isolation, and that due to a degrading transient, an Orange Path now exists on the Containment Critical Safety Function Status Tree. The operator will be directed to perform FR-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE, starting at Step 1. The operator will be expected to establish Containment Spray flow including flow from the Sodium Hydroxide Tank from at least one train of Containment Spray and manually start the C CNMT Recirculation Fan Cooler.

JPM G This is a new JPM. The operator will be told that the plant is operating at 100% power, that the Electric Plant is currently in a 50/50 NORMAL lineup, and that RG&E ECC has requested that the plant be placed in a 100/0 lineup on Circuit 767 for scheduled maintenance on offsite Circuit 7T later today. The operator will be directed to establish a 100/0 Electric Plant alignment and de-energize the 12A Station Aux Transformer per O-6.9.2, ESTABLISHING AND/OR TRANSFERRING OFFSITE POWER TO BUS 12A / BUS 12B, Section 6.3. The operator will be expected to transfer 4160V buses from a 50/50 NORMAL Lineup to 100/0 Lineup on Circuit 767 and de-energize the 12A Station Aux Transformer per Section 6.3.2 and 6.3.3 of O-6.9.2.

JPM I This is a Bank JPM. The operator will be told that the D Gas Decay Tank (GDT) is full and approved for release, that the D GDT does NOT have elevated activity and the contents are not from VCT gas and that Procedure S-4.2.5, Release of Gas Decay Tank, is in progress with the procedure signed off through Section 5.0. After being told that the Extra EO has removed the required tagout and completed the necessary paperwork, the operator will be directed to release the D GDT in accordance with S-4.2.5, Release of Gas Decay Tank. The operator will be expected to lineup and release the D GDT in accordance with S-4.2.5, Section 6.4 and then stop the release in accordance with S-4.2.5, Step 4.2 upon an alarm condition on R-14 (Alternate Path). This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

JPM J This is a Bank JPM. The operator will be told that the plant has experienced a LOCA outside of Containment, which cannot be isolated; and that the crew has entered ECA-1.1, Loss of Coolant Recirculation. The operator will be directed to transfer water from SFP to the RWST using Attachment ATT-18.0, SFP-RWST, bypassing the SFP DI and Filter. The operator will be expected to initiate a transfer of water between the Spent Fuel Pool and the RWST bypassing the SFP DI and Filter in accordance with ATT-18.0.

JPM K This is a Bank JPM. The operator will be told that there has been a loss of the 480V safeguards buses, the crew is currently in ECA-0.0, Loss of All AC Power and the TDAFW has been running for one and a half hours with fire water not available. The operator will be directed to align self-cooling to the TDAFW pump per ATT-5.2, ALTERNATE COOLING TO TDAFW PUMP, Part B. The operator will be expected to align self-cooling to the TDAFW pump in accordance with ATT-5.2, ATTACHMENT ALTERNATE COOLING TO TDAFW PUMP within 30 minutes. This is a Time Critical JPM.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

Facility: Ginna Date of Examination: 10/2020 Exam Level (circle one): SRO(U) Operating Test No.: N20-1 Control Room Systems@ (8 for RO; 7 for SRO-I; 2 or 3 for SRO-U)

Type Code* Safety System / JPM Title Function 004 Chemical and Volume Control System [004 A4.07 (3.9/3.7)]

A.

S, P, D, A, L 1 Borate for one rod not fully inserted following trip per ES-0.1 B. 008 Component Cooling Water [008 A2.01 (3.3\3.6)]

Initiating a Plant Heatup on RHR w/Subsequent Failure of CCW Pump S, N, A, L 8 006 Emergency Core Cooling System [006 A1.13 (3.5/3.7)]

C.

S, D, EN 2 Makeup to the B Accumulator from the RWST NA D.

NA E.

NA F.

NA G.

NA H.

In-Plant Systems:* 3 for RO; 3 for SRO-I; 3 or 2 for SRO-U I. 071 Waste Gas Disposal System [071 A3.03 (3.6/3.8)]

P, D, R, A 9 Release D Gas Decay Tank J. E04 LOCA Outside Containment [E04 EA2.2 (3.6/4.2)]

D, R, E 3 Perform SFP-RWST Attachment K. NA

All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions, all five SRO-U systems must serve different safety functions, and in-plant systems and functions may overlap those tested in the control room.

NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 2-3 (3)

(C)ontrol room (D)irect from bank 4 (4)

(E)mergency or abnormal in-plant 1 (1)

(EN)gineered Safety Feature 1 (1) (Control Room System)

(L)ow-Power / Shutdown 1 (2)

(N)ew or (M)odified from bank including 1(A) 1 (1)

(P)revious 2 exams 2 (2) (Randomly Selected)

(R)CA 1 (2)

(S)imulator JPM Summary JPM A This is a Bank JPM. The operator will be told that the plant has experienced a reactor trip and that the crew has completed ES-0.1, REACTOR TRIP RESPONSE, through step 3.

After being told that another operator will handle all other MCB operations and alarms not associated with the assigned task, the operator will be directed to perform Step 4 of ES-0.1 (Verify MRPI Indicates - ALL CONTROL AND SHUTDOWN RODS ON BOTTOM).

The operator will be expected to determine that one control rod has not fully inserted in accordance with Step 4 of ES-0.1 and attempt to initiate boration via the normal method.

When it is discovered that boration cannot be started in accordance with step 4 RNO of ES-0.1 (Alternate Path), the operator will initiate RCS boration in accordance with ER-CVCS.1, Section 6.2.1. This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

JPM B This is a new JPM. The operator will be told that the plant is in Mode 5, that the crew has completed Section 6.5 of O-1.1, PLANT HEATUP FROM COLD SHUTDOWN TO HOT SHUTDOWN, the current RCS heatup rate is 13F/hour that Chemistry has completed all required RCS sampling and has added Hydrazine and that another operator is standing by to monitor and plot heatup rate. The operator will be directed to initiate an RCS heatup at maximum rate not to exceed 50°F/Hour with a maximum RHR System Total Flow of 1500 gpm by performing steps 6.6.1 through 6.6.3 Section 6.6 of O-1.1. The operator will be expected to raise the RCS heatup rate in accordance with section 6.6 of O-1.1 to between 20-50F/hour, and then respond to a loss of CCW by attempting to start the B CCW Pump and stopping the RCPs prior to Motor Bearing Temperature reaching 266F when this fails in accordance with AP-CCW.3 (Alternate Path).

JPM C This is a Bank JPM. The operator will be told that AR-C-4, ACCUMULATOR 1B (LOOP A) LEVEL 60 % 75, has alarmed. The operator will be directed to refill the B Accumulator to 69% using the C SI Pump. The operator will be expected to start the C SI Pump and raise the level of the B Accumulator to 69% in accordance with Section 6.2 of S-16.13, RWST WATER MAKEUP TO THE ACCUMULATORS, without the B Accumulator Level rising to greater than 75%.

JPM I This is a Bank JPM. The operator will be told that the D Gas Decay Tank (GDT) is full and approved for release, that the D GDT does NOT have elevated activity and the contents are not from VCT gas and that Procedure S-4.2.5, Release of Gas Decay Tank, is in progress with the procedure signed off through Section 5.0. After being told that the NUREG-1021, Revision 11

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 (REV_071020)

Extra EO has removed the required tagout and completed the necessary paperwork, the operator will be directed to release the D GDT in accordance with S-4.2.5, Release of Gas Decay Tank. The operator will be expected to lineup and release the D GDT in accordance with S-4.2.5, Section 6.4 and then stop the release in accordance with S-4.2.5, Step 4.2 upon an alarm condition on R-14 (Alternate Path). This JPM appeared on the 2018 Initial License Exam and was randomly selected for the 2020 Exam.

JPM J This is a Bank JPM. The operator will be told that the plant has experienced a LOCA outside of Containment, which cannot be isolated; and that the crew has entered ECA-1.1, Loss of Coolant Recirculation. The operator will be directed to transfer water from SFP to the RWST using Attachment ATT-18.0, SFP-RWST, bypassing the SFP DI and Filter. The operator will be expected to initiate a transfer of water between the Spent Fuel Pool and the RWST bypassing the SFP DI and Filter in accordance with ATT-18.0.

NUREG-1021, Revision 11

Appendix D Scenario Outline Form ES-D-1 (Rev_090920)

Facility: Ginna Scenario No.: 1 Op Test No.: N20-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 100% power (EOL). The area has experienced unseasonably hot weather with no precipitation. It is expected to maintain power stable at the current power level throughout the shift.

Turnover: The following equipment is Out-Of-Service: Containment Recirculation Fan Cooler C (TS 3.6.6 Condition D Action D.1) is OOS for breaker maintenance, and the Condensate Booster Pump A is OOS for thrust bearing replacement. The A RHR Pump has been taken out of service for testing. (TS 3.5.2 Condition A Action A.1).

Critical Tasks: See Below Event Malf. Event Type* Event No. No. Description MAL 1 C-RO Failure of A RHR Pump During Surveillance/Failure of the Electric CLG05 C-SRO Fire Pump ANNARHR 02 TS 2 MAL I-RO Pressurizer Pressure (PT-449) fails HIGH (CT-1)

PZR02D I-BOP I-SRO TS 3 MAL C-BOP A ARV Fails OPEN (3411)

STM04A C-SRO 4 REM R-RO Unscheduled Trip of Transmission Circuits/Downpower Various Circuit Bkrs C-BOP C-SRO MAL 5 C-BOP B FRV fails AS-IS (Manual Control Available) (CT-2)

FDW07C C-SRO MAL 6 M-RO Ejected Control Rod ROD05-K9 M-BOP M-SRO 7 MAL C-BOP Failure of Turbine to Trip on Rx Trip TUR02 C-SRO MAL 8 C-RO Failure of A and B SI Pumps to Auto Start (CT-3)

RPS07A RPS07B C-SRO 9 MAL C-RO B RHR Pumps trips RHR01B C-SRO

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 (Rev_090920)

Ginna 2020 NRC Scenario #1 The plant is at 100% power (EOL). The area has experienced unseasonably hot weather with no precipitation. It is expected to maintain power stable at the current power level throughout the shift.

The following equipment is Out-Of-Service: Containment Recirculation Fan Cooler C (TS 3.6.6 Condition D Action D.1) is OOS for breaker maintenance, and the Condensate Booster Pump A is OOS for thrust bearing replacement. The A RHR Pump has been taken out of service for testing.

(TS 3.5.2 Condition A Action A.1).

Shortly after taking the watch, the operator will start the A RHR Pump per STP-O-2.2.-COMP-A, Residual Heat Removal Pump A Comprehensive Test, and then stop the pump due to a pump seal water cooler failure using the guidance of A-503.1, Emergency and Abnormal Operating Procedures Users Guide. The operator will respond using AP-CCW.2, Loss of CCW During Power Operation. During this time, a failure will occur on the Electric Fire Pump Breaker and the operator will respond in accordance with AR-K-31, FIRE SYSTEM ALARM PANEL, and be required to address TR-3.7.1, Fire Suppression Water Sources.

Following this, the controlling Pressurizer Pressure Transmitter will fail HIGH, causing the Spray Valves to open. The operator will respond in accordance with AR-F-2, PRESSURIZER HIGH PRESS 2310 PSI, and AR-F-10, PRESSURIZER LO PRESS 2205 PSI, and enter AP-PRZR.1, Abnormal PZR Pressure. AP-PRZR.1 will refer the operator to ER-INST.1, Reactor Protection Bistable Defeat After Instrumentation Loop Failure, for the defeat of PT-449. The operator will address Technical Specification LCO 3.4.1, RCS Pressure, Temperature, and Flow Departure From Nucleate Boiling (DNB) Limits; LCO 3.3.1, Reactor Trip System (RTS) Instrumentation; and TR-3.4.3, Anticipated Transient Without Scram (ATWS) Mitigation.

Subsequently, the controller for the A SG ARV will fail such that the valve will travel to the fully OPEN position. The operator will respond using A-503.1, Emergency and Abnormal Operating Procedures Users Guide, and/or AP-FW.2, Secondary Coolant Leak, and take manual control of the ARV-3411 and close the valve.

Then, the off-site transmission circuit 908 will de-energize, and the RG&E Energy Control Center (ECC) will request that Ginna verbally certify that the plant is capable of ramping down to 490 MWe net generation in 14 minutes upon subsequent notification from ECC. The operator will respond in accordance with AR-J-28, STATION 13A TROUBLE, enter O-6.9, Ginna Station Operating Limits for Station 13A Transmission, and prepare for plant shutdown. After this, the off-site transmission circuit 913 will also de-energize and the ECC will call requesting that the previously agreed to downpower be executed. The operating crew will enter AP-TURB.5, Rapid Load Reduction, and lower plant power to 490 MWe.

During the load reduction, a failure of the B FRV to control in AUTO will occur. The operator will respond per AR-G-5, S/G B LEVEL DEVIATION +/-7%, or upon observing an abnormally high level in the B Steam Generator and control the B FRV manually.

After this, Shutdown Bank Control Rod K-9 will be ejected from the core causing a LOCA, and an automatic Rx Trip/SI signal will occur. On the trip the Main Turbine will fail to trip, and the operator will need to manually trip the Turbine. Additionally, the A and the B SI Pumps will fail to start automatically and the B RHR Pump will trip. The operator will be required to manually start both SI Pumps. The operator will enter E-0, Reactor Trip or Safety Injection, and transition to E-1, Loss of Reactor or Secondary Coolant.

Appendix D Scenario Outline Form ES-D-1 (Rev_090920)

The operator will transition to ECA-1.1, Loss of Emergency Coolant Recirculation, due to a loss of both RHR Pumps. The operator will take actions to minimize the inventory loss from the RWST.

The scenario will terminate at Step 10.a RNO of ECA-1.1, after the crew has stopped one SI Pump.

Critical Tasks:

Manually control PRZR pressure during the failure of PT-449 before the Reactor automatically trips due to low pressurizer pressure Safety Significance: failure to control PRZR pressure and stop the pressure transient, under the postulated plant conditions, results in an unnecessary transient to the plant and challenge to the Reactor Protection System. Performance of the critical task would stabilize the pressure transient.

A failure to stabilize the pressure transient, when able to do so, constitutes a mis-operation or incorrect crew performance which leads to incorrect RCS pressure control.

Manually control the B S/G level during the failure of the B FRV Controller before the Reactor automatically trips due to low S/G level or Feedwater Isolates due to high S/G level Safety Significance: failure to control B S/G level and stop the level transient, under the postulated plant conditions, results in an unnecessary transient to the plant and challenge to the Reactor Protection System. Performance of the critical task would stabilize the level transient. A failure to stabilize the level transient, when able to do so, constitutes a mis-operation or incorrect crew performance which leads to incorrect RCS temperature and/or pressure control.

Establish flow from at least two SI pumps before transition to E-1, Loss of Reactor or Secondary Coolant Safety Significance: Failure to manually start at least two SI pumps under the postulated conditions constitutes "mis-operation or incorrect crew performance which leads to degraded ECCS capacity."

In this case, at least two SI pumps can be manually started from the control room. Therefore, failure to manually start SI pumps also represents a "demonstrated inability by the crew to (1) Recognize a failure/incorrect auto actuation of an ESF system or component and (2) Effectively direct/manipulate ESF controls. The acceptable results obtained in the FSAR analysis of a small-break LOCA are predicated on the assumption of minimum ECCS pumped injection. The analysis assumes that a minimum pumped ECCS flow rate, which varies with RCS pressure, is injected into the core. The flow-rate values assumed for minimum pumped injection are based on operation of the following ECCS pumps: Two SI pumps and one RHR pump. Operation of this minimum required complement of ECCS injection pumps is consistent with the FSAR assumption that only minimum safeguards are actuated. Because compliance with the assumption of the FSAR is part of the facility license condition, failure to perform the critical task (under the postulated plant conditions) constitutes a violation of the license condition.

Appendix D Scenario Outline Form ES-D-1 (Rev_090920)

Facility: Ginna Scenario No.: 2 Op Test No.: N20-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 70% power (BOL). The area has experienced cool weather with no precipitation. The crew is expected to remain at this power level while maintenance is completed during the shift.

Turnover: The following equipment is Out-Of-Service: Containment Recirculation Fan Cooler C (TS 3.6.6 Condition D Action D.1) is OOS for breaker maintenance, and the B MDAFW Pump (TS 3.7.5 Condition B Action B.1) is OOS for breaker maintenance.

The A HDT Pump is OOS due to abnormal noises.

Critical Tasks: See Below Event Malf. Event Type* Event No. No. Description MAL 1 C-RO A Charging Pump Trip CVC12A C-SRO 2 MAL C-RO Fuel Failure/High RCS Activity RCS16 C-SRO TS 3 MAL C-BOP Generator Hydrogen Temperature (Cold Gas) Instrument fails GEN02 HIGH C-SRO MAL 4 C-BOP B Feed Pump Oil Leak/Trip (CT-1)

FDW04B FDW02B C-SRO OVR 5 R-RO Control Rods fail to Move in AUTO/Stuck Rod ROD04C MAL C-SRO ROD03- TS G11 MAL 6 M-RO Condensate Header Break/A Main Feedwater Pump Trip/TDAFW CND08 M-BOP Pump trips on Overspeed FDW02A FDW12 M-SRO MAL 7 C-BOP Automatic Rx Trip fails/No Manual Available (CT-2)

RPS05A RPS05B C-SRO REM 8 C-BOP Loss of Bus 14 (CT-3)

EDS04A C-SRO

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 (Rev_090920)

Ginna 2020 NRC Scenario #2 The plant is at 70% power (BOL). The area has experienced cool weather with no precipitation.

The crew is expected to remain at this power level while maintenance is completed during the shift.

The following equipment is Out-Of-Service: Containment Recirculation Fan Cooler C (TS 3.6.6 Condition D Action D.1) is OOS for breaker maintenance, and the B MDAFW Pump (TS 3.7.5 Condition B Action B.1) is OOS for breaker maintenance. The A HDT Pump is OOS due to abnormal noises.

Shortly after taking the watch, the A Charging Pump (Operating in AUTO) will trip. The operator will respond in accordance with AR-G-25, MOTOR OFF CTR SECT PMPS EXCEPT MAIN & AUX FEED PMPS, and start the B Charging Pump.

Shortly after this, a fuel failure will occur. The crew will address AR-E-24, RMS AREA MONITOR HIGH ACTIVITY, and AR-RMS-9, R9 LETDOWN LINE MONITOR, and enter AP-RCS.3, High Reactor Coolant Activity. After Chemistry reports that Dose Equivalent Iodine is 13 µCi/gram, the operator will place the 60 GPM letdown orifice in service, in accordance with S-3.2P, Swapping CVCS Letdown Orifice Valves. The operator will address Technical Specification LCO 3.4.16, RCS Specific Activity, and EPIP 1.13, Local Radiation Emergency.

Following this, the Generator Hydrogen Temperature (Cold Gas/TT-2023) Instrument will fail HIGH causing the Temperature Controller to increase cooling flow to the Main Generator, and Generator Gas temperatures to start to decrease. The operator will respond in accordance with AR-H-22, H2 CLR TEMP HI/BYP VLV < 70% OPEN. Using AR-H-22, the operator will take manual control of the Generator Hydrogen Temp Controller (TC-2023), as necessary, to control Generator Gas Temperature.

After this, the B Main Feedwater Pump will develop an oil leak, and trip within 60 seconds. The operator will respond using AR-H-4, MAIN FEED PUMP OIL SYSTEM, and AR-H-12, FEED PUMP DC OIL PUMP AUTO START, and enter AP-FW.1, Abnormal MFW Pump Flow or NPSH.

The operator will start the A MDAFW Pump and the TD AFW Pump and initiate a downpower in accordance with AP-TURB.5, Rapid Load Reduction.

During the downpower, the control rods will fail to move in auto and the operator will need to insert control rods manually. Additionally, Control Rod G-11 will stick in its original position. After the plant stabilizes, the operator will respond in accordance with AR-C-5, PPCS ROD SEQUENCE OR ROD DEVIATION/PPCS LTOP HI-LOW TEMPERATURE, and enter AP-RCC.2, RCC/RPI Malfunction.

The operator will address Technical Specification LCO 3.1.4, Rod Group Alignment Limits, and LCO 3.2.4, Quadrant Power Tilt Ratio.

After this, a large rupture will occur in the Condensate Header resulting in a loss of feedwater. The automatic Rx Trip system will fail to trip the reactor, and the operator will need to manually trip the reactor from the MCB by de-energizing Bus 13 and 15. The crew may enter AP-FW.2, Secondary Coolant Leak, then will enter E-0, Reactor Trip or Safety Injection, and transition to ES-0.1, Reactor Trip Response.

The TDAFW Pump will trip on overspeed on the reactor trip. Subsequently, after ES-0.1 has been entered, a ground fault will occur on Bus 14, isolating the bus and de-energizing the A MDAFW Pump. A Red condition will eventually exist on the Heat Sink Critical Safety Function, and the crew will transition to FR-H.1, Response to Loss of Secondary Heat Sink. The crew will restore AFW Appendix D Scenario Outline Form ES-D-1 (Rev_090920) flow to the Steam Generators via ATT-5.1, Attachment SAFW From SW, and ATT-22.0, Attachment Restoring Feed Flow.

The scenario will terminate at Step 12.b of FR-H.1, after the crew has returned to ES-0.1.

Critical Tasks:

Stabilize the plant during the Main Feedwater Pump Trip before the Reactor must be manually tripped at 20% or automatically trips on a low Narrow Range Steam Generator level Safety Significance: Failure to control plant power and stabilize the transient, under the postulated plant conditions, results in an unnecessary transient to the plant and challenge to the Reactor Protection System. Performance of the critical task would stabilize the transient. A failure to stabilize the transient, when able to do so (i.e. event initiates from < 75% power), constitutes a mis-operation or incorrect crew performance which leads to incorrect RCS pressure/temperature control.

Manually trip the reactor from the control room before transition to FR-S.1 Safety Significance: Failure to manually trip the reactor from the control room when able to do so (i.e. De-energize Bus 13 and 15) causes a challenge to the subcriticality CSF beyond that irreparably introduced by the postulated conditions and requires that the facility declare an ALERT based on MA3 when the Emergency Classification would have been an Unusual Event based on MU3 had the Critical Task been completed successfully. The failure to complete the Critical Task constitutes an incorrect performance that necessitates the crew taking action which complicates the event mitigation strategy demonstrating the inability by the crew to recognize and properly mitigate a failure of the automatic actuation of the RPS.

Establish feedwater flow into at least one Steam Generator before both Steam Generator Wide Range Levels lower to less than 120 inches [160 inches adverse CNMT]

Safety Significance: Failure to establish feedwater flow to any Steam Generator results in the crews having to rely upon the lower-priority action of establishing RCS bleed and feed to minimize core uncovery. This constitutes incorrect performance that leads to degradation of any barrier to fission product release. Establishing feedwater flow into the SGs offers the most effective recovery action to restore the heat sink. The introduction of feedwater flow immediately restores SG inventory and re-establishes primary-to-secondary heat transfer, decreasing RCS pressure and cooling the core.

The RCS pressure decrease then precludes the opening of the PORVs and degradation of the RCS barrier. If no form of feedwater flow is made available to the SGs, the crew must establish RCS bleed and feed on or before SG dryout. When the crew fails to simply establish available feedwater flow (as it could, given the postulated conditions) before SG dryout occurs, it necessitates the crew taking compensating action which complicates the event mitigation strategy.

Appendix D Scenario Outline Form ES-D-1 (Rev_091020)

Facility: Ginna Scenario No.: 3 Op Test No.: N20-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 50% power (MOL). The plant was taken to 50% due to a failure of the A MFW Pump. Corrective maintenance has been performed and the A MFW Pump is operating. The area has experienced unseasonably cool weather with no precipitation. The crew is expected to raise power to 100% on this shift.

Turnover: The following equipment is Out-Of-Service: The A EDG (TS 3.8.1 Condition B Action B.1, B.2, B.3.1 or B.3.2 and B.4) is OOS for fuel pump replacement and is expected to be back in 90 minutes. The A Control Rod Shroud Fan is OOS for breaker maintenance.

Critical Tasks: See Below Event Malf. Event Type* Event No. No. Description MAL 1 R-RO Load Ascension/ MRPI System Failure ROD13A-K7 N-BOP N-SRO TS 2 MAL C-BOP Main Generator Voltage Regulator Fails HIGH GEN03 C-SRO 3 MAL I-RO Letdown Temperature Control Valve (TCV-130) Controller Failure CLG14A I-SRO MAL 4 C-RO Leak in the NRHX to CCW system CLG03 C-SRO MAL 5 C-RO Loss of Offsite circuit 767/Restore 4160 Bus 12B EDS01B C-BOP C-SRO TS MAL 6 M-RO B EDG Trips/Loss of 7T Circuit (CT-3)

EDS01A GEN04B M-BOP M-SRO MAL 7 C-BOP TDAFW Steam Supply Valves fail to Auto OPEN (3504A and RPS07M C-SRO 3505A) (CT-1)

RPS07N MAL 8 C-BOP Selected Service Water Pumps fail to start in Auto (CT-2)

RPS07O C-SRO

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 (Rev_091020)

Ginna 2020 NRC Scenario #3 The plant is at 50% power (MOL). The plant was taken to 50% due to a failure of the A MFW Pump.

Corrective maintenance has been performed and the A MFW Pump is operating. The area has experienced unseasonably cool weather with no precipitation. The crew is expected to raise power to 100% on this shift.

The following equipment is Out-Of-Service: The A EDG (TS 3.8.1 Condition B Action B.1, B.2, B.3.1 or B.3.2 and B.4) is OOS for fuel pump replacement and is expected to be back in 90 minutes. The A Control Rod Shroud Fan is OOS for breaker maintenance.

Shortly after taking the watch, the operator will raise power in accordance with O-5.2, Load Ascension. The operator will address S-3.1, Boron Concentration Control, to start the load ascension using Alternate Dilute. During the load ascension, a MRPI System Failure will occur. The operator will address AR-C-29, MRPI SYSTEM FAILURE, AP-RCC.2, RCC/RPI Malfunction, and Technical Specification LCO 3.1.7, Rod Position Indication.

Subsequently, the Main Generator Voltage Regulator will fail HIGH. The operator will respond in accordance with AR-J-10, GENERATOR VOLTAGE REGULATOR MANUAL. The operator will reduce generator output voltage using the Base Adjuster and notify RG&E ECC per the NOTE in AR-J-10. The Voltage Regulator will remain in MANUAL throughout the remainder of the scenario.

Following this, the Letdown Temperature Control Valve (TCV-130) Controller will fail causing the TCV-130 to close, and actual letdown temperature to rise. The operator will respond in accordance with A-503.1, Emergency and Abnormal Operating Procedures Users Guide, Section 5.3.A.5, and should re-open TCV-130 in manual to restore normal letdown temperature. The operator will address AR-A-12, NON-REGEN HX LETDOWN OUT HI TEMP 145°F, and the TCV-130 Controller will remain in MANUAL throughout the remainder of the scenario.

Then, a 30 gpm leak will develop on the Non-Regenerative Heat Exchanger. The operator will respond in accordance with AR-E-16, RMS PROCESS MONITOR HIGH ACTIVITY, and AR-RMS-17, R-17 COMPONENT COOLING, which will direct the crew to AP-CCW.1, Leakage Into the Component Cooling Loop. Per AP-CCW.1, letdown flow through the NRHX (and the leak) will be isolated and Excess Letdown will be placed in service.

After this, a loss of offsite power circuit 767 will occur, resulting in the loss of 4160 Bus 12B. The crew will respond per AP-ELEC.1, Loss of 12A and/or 12B Busses, and restore power to 12B in accordance with ER-ELEC.1, Restoration of Offsite Power, using circuit 7T. The operator will address Technical Specification LCO 3.8.1, AC Sources - MODES 1, 2, 3, and 4, and Technical Requirements Manual, TR-3.8.1, Offsite Power Sources.

Next, the B EDG will trip and the 7T line will be lost, resulting in a Station Blackout. The operator will enter ECA-0.0, Loss of All AC Power. On the loss of power, the TDAFW Pump will fail to automatically start, and the operator will need to manually start the pump.

While in ECA-0.0 (at Step 13), the A EDG will become available. The operator will start the A EDG per Step 7 RNO actions and restore power to 480V vital busses 14 and 18. Upon restoration of power to Bus 18 the A SWP will fail to start automatically, requiring the operator to manually start the SWP. Following power restoration to Bus 14, recovery actions will continue with Step 34. The crew will likely transition to ECA-0.2, Loss of All AC Power Recovery With SI Required, based on low Pressurizer level. On the other hand, there is a possibility that the crew could transition to ECA-0.1, Loss of All AC Power Recovery Without SI Required.

Appendix D Scenario Outline Form ES-D-1 (Rev_091020)

The scenario will terminate upon completion of ECA-0.2, if the RCP Seal Injection Needle Valves are closed with no Charging Pump running. If these valves are not closed, the scenario should continue in E-1, Loss of Reactor or Secondary Coolant, until the point of Charging Pump start (Step 11). If the crew transitions to ECA-0.1, rather than ECA-0.2, terminate at Step 5 of ECA-0.1, after the crew has restored Charging flow.

Critical Tasks:

Establish the minimum required AFW flowrate to the Steam Generators before Wide Range Level in BOTH Steam Generators lowers to 50 inches (100 inches Adverse Containment)

Safety Significance: Failure to establish the minimum required AFW flowrate results in adverse consequences and/or a significant degradation of the mitigative capability of the plant. If AFW flow is not sufficient during a Station Blackout, then cooldown of the RCS cannot be accomplished, and the result would be increased thermal stress on the RCP Seals, and increase the likelihood of increased leakage. Failure to perform this task, when able to do so (i.e. manually opening TDAFW Pump Steam Supply Valve), results in mis-operation that unnecessarily reduces the margin to safety of the plant.

Manually start a Service Water Pump prior to the running Emergency Diesel Generator trips due to damage caused by engine overheating Safety Significance: Failure to manually start the SW Pump under the postulated plant conditions means that the DG is running without ESW cooling (will result in the ONLY AC Power Source running loaded without cooling water). Running the DG loaded without SW cooling leads to a high-temperature condition that can result in DG failure due to damage caused by engine overheating.

Under the postulated plant conditions, the running DG is the only operable DG. Thus, failure to perform the critical task constitutes mis-operation or incorrect crew performance that leads to degraded emergency power capacity. Even if the crew does not start the SW pump until receipt of high-temperature alarm(s), the critical task is performed satisfactorily, provided that the DG does not fail because of damage caused by engine overheating. For Ginna no automatic trip occurs from high D/G temperature. The GE/ALCO Engineering analysis states that the maximum allowable temperature for the engine will be reached in approximately 4 minutes and 23 seconds for initial standby to a full load condition (1950kW). Simulator testing under the postulated plant conditions for the Scenario showed that the EDG trips in approximately 5 minutes and 30 seconds.

Isolate RCP Seal Injection before a Charging Pump is Started Safety Significance: Failure to isolate RCP seal injection before starting a charging pump under the postulated plant conditions, can result in unnecessary and avoidable degradation of the RCS fission-product barrier, specifically at the point of the RCP seals, especially if RCPs are subsequently started. Additionally, failure to perform the critical task results in significant degradation in the mitigative capability of the plant in that the RCPs are not available for subsequent event recovery actions (except for a RED path condition on the core cooling CSF). Following restoration of ac power, it is desirable to restore RCP seal cooling as soon as practical to reduce seal temperatures and mitigate potential continued degradation of the RCP seals. However, field experience has shown that the restoration of seal cooling must be performed in a controlled manner to avoid thermal shock and related damage to pump parts. Proper restoration of RCP seal cooling is important since it (1) maximizes the availability of the RCPs if required for subsequent event recovery actions and Appendix D Scenario Outline Form ES-D-1 (Rev_091020)

(2) minimizes the possibility of seal damage that could limit subsequent plant operation due to down time to effect RCP repairs.

Appendix D Scenario Outline Form ES-D-1 (Rev_091120)

Facility: Ginna Scenario No.: 5 Op Test No.: N20-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 70% power (BOL). The area has experienced steady Thunderstorms for the past 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , with wind from the West at 10-20 mph, and this is expected to continue throughout the shift. It is expected to raise power to 100% on this shift.

Turnover: The following equipment is Out-Of-Service: Power Range Channel N44 is removed from service per ER-NIS.3 (TS LCO 3.3.1 Condition A/D/S and Action A.1, D.1 and S.1) and the QPTR Monitor has been declared inoperable. Condensate Booster Pump B is OOS for impeller replacement.

Critical Tasks: See Below Event Malf. Event Type* Event No. No. Description 1 R-RO Load Ascension/ Bus 18 Undervoltage Relay Failure MAL N-BOP A-EDS40 N-SRO TS 2 MAL C-RO VCT Divert Control Valve (LVC-112A) Failure CVC09 C-SRO 3 MAL I-SRO Power Range N42 Upper Detector Failure NIS06C TS 4 OVR C-BOP Hotwell Level Controller fails to Full Makeup CND11B C-SRO 5 MAL C-RO Circ Water Pump A Trips/Loss of Vacuum CRC01A CND07B C-BOP C-SRO MAL 6 M-RO Inadvertent Steam Line Isolation Signal STM05A/B M-BOP M-SRO MAL 7 C-RO Failure of the Reactor to trip from the Control Room/ATWS (CT-1)

RPS05A/B C-BOP C-SRO MAL 8 C-BOP One S/G Safety Valve on each S/G Lifts and sticks partially OPEN STM09A/B C-SRO (CT-2)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 (Rev_091120)

Ginna 2020 NRC Scenario #5 The plant is at 70% power (BOL). The area has experienced steady Thunderstorms for the past 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , with wind from the West at 10-20 mph, and this is expected to continue throughout the shift.

It is expected to raise power to 100% on this shift.

The following equipment is Out-Of-Service: Power Range Channel N44 is removed from service per ER-NIS.3 (TS LCO 3.3.1 Condition A/D/S and Action A.1, D.1 and S.1) and the QPTR Monitor has been declared inoperable. Condensate Booster Pump B is OOS for impeller replacement.

Shortly after taking the watch, the operator will raise power in accordance with O-5.2, Load Ascension. The operator will address S-3.1, Boron Concentration Control, to start the load ascension using Alternate Dilute. During the load ascension, a Bus 18 Undervoltage Relay will fail.

The operator will address Technical Specification LCO 3.3.4, Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation.

Shortly after this, VCT or Holdup Tank Divert Valve, LCV-112A, will fail to the FULL DIVERT position.

The operator will respond in accordance with A-503.1, Emergency and Abnormal Operating Procedures Users Guide, and place the control switch for LCV-112A to the VCT position. The operator will enter AP-CVCS.1, CVCS Leak.

Following this, the N42 Power Range Upper Detector will fail LOW. The operator will enter ER-NIS.3, PR Malfunction, however, removing N42 from service per this procedure will result in a plant trip.

The operator will address Technical Specification LCO 3.3.1, Reactor Trip System (RTS)

Instrumentation, and implement Technical Specification LCO 3.0.3. The operator will also address Technical Requirement 3.2.3, Axial Flux Difference (AFD) Monitor.

Then, the Hotwell Level Controller will fail to Full Makeup. The operator will respond in accordance with A-503.1, Emergency and Abnormal Operating Procedures Users Guide, and/or AR-PPCS-L2022A and B, CONDENSATE STORAGE TANK A(B) LEVEL, and manually control the hotwell level for the remainder of the scenario.

Next, the A Circ Water Pump will trip. Simultaneously, a Condenser Expansion Joint low-level condition will occur. The crew will respond in accordance with AR-J-16, MOTOR OFF CW-EH EMERG OIL SEAL OIL BU, and enter AP-CW.1, Loss of a Circ Water Pump, and/or AP-TURB.4, Loss of Condenser Vacuum. The crew will reduce load per AP-TURB.5, Rapid Load Reduction, as needed to stabilize Turbine Backpressure.

After this, an inadvertent Steam Line Isolation Signal will occur and both MSIVs will close. The reactor will fail to automatically trip, and the operator will attempt to trip the reactor manually. The crew will enter E-0, Reactor Trip or Safety Injection.

The reactor will fail to trip manually from the control room, and the crew will enter FR-S.1, Response to Reactor Restart/ATWS. On the trip one S/G Safety Valve on each S/G lifted and stuck partially OPEN.

The crew will successfully de-energize the Rod Drive MG set(s) causing the control rods to drop into the core. Upon completion of FR-S.1, the crew will transition back to E-0, and then to E-2, Faulted Steam Generator Isolation. While implementing E-2, the crew will recognize that both S/Gs are faulted and transition to ECA-2.1, Uncontrolled Depressurization of Both Steam Generators. The crew may take a pre-emptive action of throttling AFW flow to both S/Gs per A-503.1, Emergency and Abnormal Operating Procedures Users Guide.

Appendix D Scenario Outline Form ES-D-1 (Rev_091120)

The scenario will terminate at Step 7 of ECA-2.1, after the crew has stopped the RHR Pumps.

Critical Tasks:

Upon diagnosing an ATWS, manually insert the control rods within 1 minute, and continue insertion until the reactor is tripped or the rods are on the bottom Safety Significance: failure to insert negative reactivity, under the postulated plant conditions, results in an unnecessary situation in which the reactor power remains higher than it otherwise would if the action is taken. Performance of the critical task would move the reactor power lower to prevent a subsequent and unnecessary challenge to reactor core operational limits. A failure to insert negative reactivity constitutes a mis-operation or incorrect crew performance which leads to incorrect reactivity control. According to Section 15.8.3.2 of the Ginna UFSAR it is assumed that manual rod insertion of at least one bank is initiated within the first 60 seconds of the ATWS event.

Control the AFW flowrate to 50 gpm per SG in order to minimize the RCS Cooldown rate before a severe challenge (Orange Path) develops to the integrity CSF Safety Significance: Failure to control the AFW flow rate to the SGs leads to an unnecessary and avoidable extreme challenge to the integrity CSF. Also, failure to perform the Critical Task increases challenges to the SUBCRITICALITY Critical Safety Function which otherwise would not occur. If the action is not taken an unnecessary Orange Path could develop on the RCS Integrity Critical Safety Function requiring a substantial change in the mitigation strategy.

ES-401 PWR Examination Outline Form ES-401-2 Facility: Ginna Nuclear Power Plant Date of Exam: October 5 - 29, 2020 RO K/A Category Points SRO-Only Points Tier Group K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G* Total A2 G* Total

1. 1 3 3 3 3 3 3 18 3 3 6 Emergency and Abnormal Plant 2 1 2 1 N/A 2 2 N/A 1 9 3 1 4 Evolutions Tier Totals 4 5 4 5 5 4 27 6 4 10 1 2 2 3 3 3 2 3 3 2 3 2 28 2 3 5 2.

Plant 2 1 1 1 1 1 1 1 1 0 1 1 10 1 1 1 3 Systems Tier Totals 3 3 4 4 4 3 4 4 2 4 3 38 4 4 8

3. Generic Knowledge and Abilities 1 2 3 4 10 1 2 3 4 7 Categories 3 3 2 2 2 2 1 2 Note: 1. Ensure that at least two topics from every applicable K/A category are sampled within each tier of the RO and SRO-only outline sections (i.e., except for one category in Tier 3 of the SRO-only section, the Tier Totals in each K/A category shall not be less than two). (One Tier 3 radiation control K/A is allowed if it is replaced by a K/A from another Tier 3 category.)

2. The point total for each group and tier in the proposed outline must match that specified in the table. The final point total for each group and tier may deviate by +/-1 from that specified in the table based on NRC revisions. The final RO exam must total 75 points, and the SRO-only exam must total 25 points.

3. Systems/evolutions within each group are identified on the outline. Systems or evolutions that do not apply at the facility should be deleted with justification. Operationally important, site-specific systems/evolutions that are not included on the outline should be added. Refer to Section D.1.b of ES-401 for guidance regarding the elimination of inappropriate K/A statements.

4. Select topics from as many systems and evolutions as possible. Sample every system or evolution in the group before selecting a second topic for any system or evolution.

5. Absent a plant-specific priority, only those K/As having an importance rating (IR) of 2.5 or higher shall be selected. Use the RO and SRO ratings for the RO and SRO-only portions, respectively.

6. Select SRO topics for Tiers 1 and 2 from the shaded systems and K/A categories.

7. The generic (G) K/As in Tiers 1 and 2 shall be selected from Section 2 of the K/A catalog, but the topics must be relevant to the applicable evolution or system. Refer to Section D.1.b of ES-401 for the applicable K/As.

8. On the following pages, enter the K/A numbers, a brief description of each topic, the topics IRs for the applicable license level, and the point totals (#) for each system and category. Enter the group and tier totals for each category in the table above. If fuel-handling equipment is sampled in a category other than Category A2 or G* on the SRO-only exam, enter it on the left side of Column A2 for Tier 2, Group 2. (Note 1 does not apply). Use duplicate pages for RO and SRO-only exams.

9. For Tier 3, select topics from Section 2 of the K/A catalog and enter the K/A numbers, descriptions, IRs, and point totals (#) on Form ES-401-3. Limit SRO selections to K/As that are linked to 10 CFR 55.43.

G* Generic K/As

These systems/evolutions must be included as part of the sample (as applicable to the facility) when Revision 3 of the K/A catalog is used to develop the sample plan. They are not required to be included when using earlier revisions of the K/A catalog.

- These systems/evolutions may be eliminated from the sample (as applicable to the facility) when Revision 3 of the K/A catalog is used to develop the sample plan.

ES-401 2 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Emergency and Abnormal Plant EvolutionsTier 1/Group 1 (RO)

E/APE # / Name / Safety Function K1 K2 K3 A1 A2 G* K/A Topic(s) IR #

EA2.05 - Ability to determine or interpret the 000007 (EPE 7; BW E02&E10; CE E02) 05 following as they apply to a reactor trip: Reactor trip Reactor Trip, Stabilization, Recovery / 1 3.4 1 first-out indication.

(CFR: 41.7 / 45.5 / 45.6)

AK1.01 - Knowledge of the operational implications 000008 (APE 8) Pressurizer Vapor Space 01 of the following concepts as they apply to a Accident / 3 Pressurizer Vapor Space Accident:

3.2 2 Thermodynamics and flow characteristics of open or leaking valves.

(CFR: 41.8 / 41.10 / 45.3)

G2.1.19 - Ability to use plant computers to evaluate 000009 (EPE 9) Small Break LOCA / 3 01. system or component status. 3.9 3 19 (CFR: 41.10 / 45.12)

EA1.01 - Ability to operate and monitor the 000011 (EPE 11) Large Break LOCA / 3 01 following as they apply to a Large Break LOCA:

Control of RCS pressure and temperature to avoid 3.7 4 violating PTS limits.

(CFR: 41.7 / 45.5 / 45.6) 000015 (APE 15) Reactor Coolant Pump Malfunctions / 4 AA2.04 - Ability to determine and interpret the 000022 (APE 22) Loss of Reactor Coolant 04 following as they apply to the Loss of Reactor Makeup / 2 Coolant Makeup: How long PZR level can be 2.9 5 maintained within limits.

(CFR: 43.5 / 45.13)

AK1.01 - Knowledge of the operational implications 000025 (APE 25) Loss of Residual Heat 01 of the following concepts as they apply to Loss of Removal System / 4 Residual Heat Removal System: Loss of RHRS 3.9 6 during all modes of operation.

(CFR: 41.8 / 41.10 / 45.3) 000026 (APE 26) Loss of Component Cooling Water / 8 AK2.03 - Knowledge of the interrelations between 000027 (APE 27) Pressurizer Pressure 03 the Pressurizer Pressure Control Malfunctions and Control System Malfunction / 3 2.6 7 the following: Controllers and positioners.

(CFR: 41.7 / 45.7)

EK3.08 - Knowledge of the reasons for the 000029 (EPE 29) Anticipated Transient 08 following responses as they apply to the ATWS:

Without Scram / 1 3.6 8 Closing the main steam isolation valve.

(CFR: 41.5 / 41.10 / 45.6 / 45.13)

EK3.06 - Knowledge of the reasons for the 000038 (EPE 38) Steam Generator Tube 06 following responses as they apply to the SGTR:

Rupture / 3 Actions contained in EOP for RCS water inventory 4.2 9 balance, S/G tube rupture, and plant shutdown procedures.

(CFR: 41.5 / 41.10 / 45.6 / 45.13)

AK2.02 - Knowledge of the interrelations between 000040 (APE 40; BW E05; CE E05; W E12) 02 the Steam Line Rupture and the following: Sensors Steam Line RuptureExcessive Heat 2.6 10 and detectors.

Transfer / 4 (CFR: 41.7 / 45.7)

AK3.03 - Knowledge of the reasons for the 000054 (APE 54; CE E06) Loss of Main 03 following responses as they apply to the Loss of Feedwater /4 Main Feedwater (MFW): Manual control of AFW 3.8 11 flow control valves.

(CFR: 41.5 / 41.10 / 45.6 / 45.13)

EA1.07 - Ability to operate and monitor the 000055 (EPE 55) Station Blackout / 6 07 following as they apply to a Station Blackout:

4.3 12 Restoration of power from offsite.

(CFR: 41.7 / 45.5 / 45.6)

G2.4.6 - Knowledge of EOP mitigation strategies.

000056 (APE 56) Loss of Offsite Power / 6 04. (CFR: 41.10 / 43.5 / 45.13) 3.7 13 06

ES-401 3 Form ES-401-2 AA2.18 - Ability to determine and interpret the 000057 (APE 57) Loss of Vital AC 18 following as they apply to the Loss of Vital AC Instrument Bus / 6 Instrument Bus: The indicator, valve, breaker, or 3.1 14 damper position which will occur on a loss of power.

(CFR: 43.5 / 45.13)

G2.4.45 - Ability to prioritize and interpret the 000058 (APE 58) Loss of DC Power / 6 04. significance of each annunciator or alarm. 4.1 15 45 (CFR: 41.10 / 43.5 / 45.3 / 45.12) 000062 (APE 62) Loss of Nuclear Service Water / 4 000065 (APE 65) Loss of Instrument Air / 8 000077 (APE 77) Generator Voltage and Electric Grid Disturbances / 6 W E04: EK1.3 - Knowledge of the operational (W E04) LOCA Outside Containment / 3 03 implications of the following concepts as they apply to the (LOCA Outside Containment): Annunciators and conditions indicating signals, and remedial 3.5 16 actions associated with the (LOCA Outside Containment).

(CFR: 41.8 / 41.10 / 45.3)

W E11: EK2.1 - Knowledge of the interrelations (W E11) Loss of Emergency Coolant 01 between the (Loss of Emergency Coolant Recirculation / 4 Recirculation) and the following: Components, and functions of control and safety systems, including 3.6 17 instrumentation, signals, interlocks, failure modes, and automatic and manual features.

(CFR: 41.7 45.7)

W E05: EA1.1 - Ability to operate and/or monitor (BW E04; W E05) Inadequate Heat 01 the following as they apply to the (Loss of TransferLoss of Secondary Heat Sink / 4 Secondary Heat Sink): Components, and functions of control and safety systems, including 4.1 18 instrumentation, signals, interlocks, failure modes, and automatic and manual features.

(CFR: 41.7 / 45.5 / 45.6)

K/A Category Totals: 3 3 3 3 3 3 Group Point Total: 18

ES-401 4 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Emergency and Abnormal Plant EvolutionsTier 1/Group 2 (RO)

E/APE # / Name / Safety Function K1 K2 K3 A1 A2 G* K/A Topic(s) IR #

000001 (APE 1) Continuous Rod Withdrawal / 1 000003 (APE 3) Dropped Control Rod / 1 000005 (APE 5) Inoperable/Stuck Control Rod / 1 02 AK3.02 - Knowledge of the 3.6 19 reasons for the following responses as they apply to the Inoperable / Stuck Control Rod:

Rod insertion limits.

(CFR: 41.5 / 41.10 / 45.6 / 45.13) 000024 (APE 24) Emergency Boration / 1 000028 (APE 28) Pressurizer (PZR) Level Control 03 AK2.03 - Knowledge of the 2.6 20 Malfunction / 2 interrelations between the Pressurizer Level Control Malfunctions and the following:

Controllers and positioners.

(CFR: 41.7 / 45.7) 000032 (APE 32) Loss of Source Range Nuclear 02. G2.2.39 - Knowledge of less than 3.9 21 Instrumentation / 7 39 or equal to one hour Technical Specification action statements for systems.

(CFR: 41.7 / 41.10 / 43.2 / 45.13) 000033 (APE 33) Loss of Intermediate Range Nuclear Instrumentation / 7 000036 (APE 36; BW/A08) Fuel-Handling Incidents / 8 000037 (APE 37) Steam Generator Tube Leak / 3 000051 (APE 51) Loss of Condenser Vacuum / 4 000059 (APE 59) Accidental Liquid Radwaste Release / 9 000060 (APE 60) Accidental Gaseous Radwaste Release / 9 01 AA1.01 - Ability to operate and/or 2.8 22 monitor the following as they apply to the Accidental Gaseous Radwaste: Area radiation monitors.

(CFR: 41.7 / 45.5 / 45.6) 000061 (APE 61) Area Radiation Monitoring System Alarms

/7 000067 (APE 67) Plant Fire On Site / 8 000068 (APE 68; BW A06) Control Room Evacuation / 8 06 AA2.06 - Ability to determine and 4.1 23 interpret the following as they apply to the Control Room Evacuation: RCS pressure.

(CFR: 43.5 / 45.13) 000069 (APE 69; W E14) Loss of Containment Integrity / 5 000074 (EPE 74; W E06 & E07) Inadequate Core Cooling /

4 000076 (APE 76) High Reactor Coolant Activity / 9 01 AK2.01 - Knowledge of the 2.6 24 interrelations between the High Reactor Coolant Activity and the following: Process radiation monitors.

(CFR: 41.7 / 45.7) 000078 (APE 78*) RCS Leak / 3 (W E01 & E02) Rediagnosis & SI Termination / 3 (W E13) Steam Generator Overpressure / 4

ES-401 5 Form ES-401-2 (W E15) Containment Flooding / 5 01 W E15: EA1.1 - Ability to operate 2.9 25 and/or monitor the following as they apply to the (Containment Flooding): Components, and functions of control and safety systems, including instrumentation, signals, interlocks, failure modes, and automatic and manual features.

(CFR: 41.7 / 45.5 / 45.6)

(W E16) High Containment Radiation /9 (BW A01) Plant Runback / 1 (BW A02 & A03) Loss of NNI-X/Y/7 (BW A04) Turbine Trip / 4 (BW A05) Emergency Diesel Actuation / 6 (BW A07) Flooding / 8 (BW E03) Inadequate Subcooling Margin / 4 (BW E08; W E03) LOCA CooldownDepressurization / 4 (BW E09; CE A13**; W E09 & E10) Natural Circulation/4 01 W E10: EA2.1 - Ability to 3.2 26 determine and interpret the following as they apply to the (Natural Circulation with Steam Void in Vessel with/without RVLIS): Facility conditions and selection of appropriate procedures during abnormal and emergency operations.

(CFR: 43.5 / 45.13)

(BW E13 & E14) EOP Rules and Enclosures (CE A11**; W E08) RCS OvercoolingPressurized Thermal 01 W E08: EK1.1 - Knowledge of the 3.5 27 Shock / 4 operational implications of the following concepts as they apply to the (Pressurized Thermal Shock): Components, capacity,,

and function of emergency systems.

(CFR: 41.8 / 41.10 / 45.3 (CE A16) Excess RCS Leakage / 2 (CE E09) Functional Recovery (CE E13*) Loss of Forced Circulation/LOOP/Blackout / 4 K/A Category Point Totals: 1 1 2 2 2 1 Group Point Total: 9

ES-401 6 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Plant SystemsTier 2/Group 1 (RO)

System # / Name K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G* K/A Topic(s) IR #

K5.03 - Knowledge of the operational 003 (SF4P RCP) Reactor Coolant 03 implications of the following concepts as 3.1 28 Pump they apply to the RCPS: Effects of RCP shutdown on T-ave., including the reason for the unreliability of T-ave. in the shutdown loop.

(CFR: 41.5 / 45.7)

A4.06 - Ability to manually operate and/or 004 (SF1; SF2 CVCS) Chemical and 06 monitor in the control room: Letdown 3.6 29 Volume Control isolation and flow control valves.

(CFR: 41.7 / 45.5 to 45.8) 02 K5.02 - Knowledge of the operational 3.5 30 implications of the following concepts as they apply to the CVCS: Explosion hazard associated with hydrogen containing systems.

(CFR: 41.5 / 45.7)

K4.01 - Knowledge of RHRS design 005 (SF4P RHR) Residual Heat 01 feature(s) and/or interlock(s) which provide 3.0 31 Removal for the following: Overpressure mitigation system.

(CFR: 41.7)

K2.02 - Knowledge of bus power supplies 006 (SF2; SF3 ECCS) Emergency 02 to the following: Valve operators for 2.5 32 Core Cooling accumulators.

(CFR: 41.7)

K4.01 - Knowledge of PRTS design 007 (SF5 PRTS) Pressurizer 01 feature(s) and/or interlock(s) which provide 2.6 33 Relief/Quench Tank for the following: Quench tank cooling.

(CFR: 41.7)

A1.01 - Ability to predict and/or monitor 008 (SF8 CCW) Component Cooling 01 changes in parameters (to prevent 2.8 34 Water exceeding design limits) associated with operating the CCWS controls including:

CCW flow rate.

(CFR: 41.5 / 45.5)

K2.03 - Knowledge of bus power supplies 010 (SF3 PZR PCS) Pressurizer 03 to the following: Indicator for PORV position. 2.8 35 Pressure Control (CFR: 41.7)

K3.01 - Knowledge of the effect that a loss 012 (SF7 RPS) Reactor Protection 01 or malfunction of the RPS will have on the 3.9 36 following: CRDS.

(CFR: 41.7 / 45.6) 06 A3.06 - Ability to monitor automatic 3.7 37 operation of the RPS, including: Trip logic.

(CFR: 41.7 / 45.5)

K6.01 - Knowledge of the effect that a loss 013 (SF2 ESFAS) Engineered Safety 01 or malfunction of the following will have on 2.7 38 Features Actuation the ESFAS: Sensors and detectors.

(CFR: 41.7 / 45.5 to 45.8)

ES-401 7 Form ES-401-2 A1.02 - Ability to predict and/or monitor 022 (SF5 CCS) Containment Cooling 02 changes in parameters (to prevent 3.6 39 exceeding design limits) associated with operating the CCS controls including:

Containment pressure (CFR: 41.5 / 45.5) 05 A2.05 - Ability to (a) predict the impacts of 3.1 40 the following malfunctions or operations on the CCS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Major leak in CCS.

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 025 (SF5 ICE) Ice Condenser A4.05 - Ability to manually operate and/or 026 (SF5 CSS) Containment Spray 05 monitor in the control room: Containment 3.5 41 spray reset switches.

(CFR: 41.7 / 45.5 to 45.8)

A3.02 - Ability to monitor automatic 039 (SF4S MSS) Main and Reheat 02 operation of the MRSS, including: Isolation 3.1 42 Steam of the MRSS.

(CFR: 41.5 / 45.5)

A4.11 - Ability to manually operate and 059 (SF4S MFW) Main Feedwater 11 monitor in the control room: Recovery from 3.1 43 automatic feedwater isolation.

(CFR: 41.7 / 45.5 to 45.8)

01. G2.1.28 - Knowledge of the purpose and 4.1 44 28 function of major system components and controls.

(CFR: 41.7)

K5.02 - Knowledge of the operational 061 (SF4S AFW) Auxiliary/Emergency 02 implications of the following concepts as 3.2 45 Feedwater they apply to the AFW: Decay heat sources and magnitude.

(CFR: 41.5 / 45.7)

K6.02 - Knowledge of the effect that a loss 02 or malfunction of the following will have on 2.6 46 the AFW components: Pumps.

(CFR: 41.7 / 45.7)

A1.01 - Ability to predict and/or monitor 062 (SF6 ED AC) AC Electrical 01 changes in parameters (to prevent 3.4 47 Distribution exceeding design limits) associated with operating the AC distribution system controls including: Significance of D/G load limits.

(CFR: 41.5 / 45.5)

G2.2.12 - Knowledge of surveillance 063 (SF6 ED DC) DC Electrical 02. procedures. 3.7 48 Distribution 12 (CFR: 41.10 / 45.13) 02 K3.02 - Knowledge of the effect that a loss 3.5 49 or malfunction of the DC electrical system will have on the following: Components using DC control power.

(CFR: 41.7 / 45.6)

K1.02 - Knowledge of the physical 064 (SF6 EDG) Emergency Diesel 02 connections and/or cause-effect 3.1 50 Generator relationships between the ED/G system and the following systems: D/G cooling water system.

(CFR: 41.2 to 41.9 / 45.7 to 45.8)

ES-401 8 Form ES-401-2 A2.02 - Ability to (a) predict the impacts of 073 (SF7 PRM) Process Radiation 02 the following malfunctions or operations on 2.7 51 Monitoring the PRM system; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Detector failure.

(CFR: 41.5 / 43.5 / 45.3 / 45.13)

K4.01 - Knowledge of PRM system design 01 feature(s) and/or interlock(s) which provide 4.0 52 for the following: Release termination when radiation exceeds setpoint.

(CFR: 41.7)

K3.07 - Knowledge of the effect that a loss 076 (SF4S SW) Service Water 07 or malfunction of the SWS will have on the 3.7 53 following: ESF loads.

(CFR: 41.7 / 45.6)

K1.05 - Knowledge of the physical 078 (SF8 IAS) Instrument Air 05 connections and/or cause-effect 3.4 54 relationships between the IAS and the following systems: MSIV air.

(CFR: 41.2 to 41.9 / 45.7 to 45.8)

A2.04 - Ability to (a) predict the impacts of 103 (SF5 CNT) Containment 04 the following malfunctions or operations on 3.5 55 the containment system; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Containment evacuation (including recognition of the alarm).

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 053 (SF1; SF4P ICS*) Integrated Control K/A Category Point Totals: 2 2 3 3 3 2 3 3 2 3 2 Group Point Total: 28

ES-401 9 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Plant SystemsTier 2/Group 2 (RO)

System # / Name K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G* K/A Topic(s) IR #

001 (SF1 CRDS) Control Rod Drive 11 A4.11 - Ability to manually operate and/or 3.5 56 monitor in the control room: Determination of SDM.

(CFR: 41.7 / 45.5 to 45.8) 002 (SF2; SF4P RCS) Reactor Coolant 011 (SF2 PZR LCS) Pressurizer 01 K2.01 - Knowledge of bus power supplies to 3.1 57 Level Control the following: Charging pumps.

(CFR: 41.7) 014 (SF1 RPI) Rod Position Indication 015 (SF7 NI) Nuclear Instrumentation 016 (SF7 NNI) Nonnuclear Instrumentation 017 (SF7 ITM) In-Core Temperature 02 K4.02 - Knowledge of ITM system design 3.1 58 Monitor feature(s) and/or interlock(s) which provide for the following: Sensing and determination of location core hot spots.

(CFR: 41.7) 027 (SF5 CIRS) Containment Iodine Removal 028 (SF5 HRPS) Hydrogen 01 K6.01 - Knowledge of the effect that a loss or 2.6 59 Recombiner and Purge Control malfunction of the following will have on the HRPS: Hydrogen recombiners.

(CFR: 41.7 / 45.7) 029 (SF8 CPS) Containment Purge 033 (SF8 SFPCS) Spent Fuel Pool Cooling 034 (SF8 FHS) Fuel-Handling Equipment 035 (SF 4P SG) Steam Generator 02. G2.2.44 - Ability to interpret control room 4.2 60 44 indications to verify the status and operation of a system, and understand how operator actions and directives affect plant and system conditions.

(CFR: 41.5 / 43.5 / 45.12) 041 (SF4S SDS) Steam 02 A1.02 - Ability to predict and/or monitor 3.1 61 Dump/Turbine Bypass Control changes in parameter (to prevent exceeding design limits) associated with operating the SDS controls including: Steam pressure.

(CFR: 41.5 / 45.5) 045 (SF 4S MTG) Main Turbine 01 K5.01 - Knowledge of the operational 2.8 62 Generator implications of the following concepts as they apply to the MT/B System: Possible presence of explosive mixture in generator if hydrogen purity deteriorates.

(CFR: 41.5 / 45.7) 055 (SF4S CARS) Condenser Air Removal 056 (SF4S CDS) Condensate 03 K1.03 - Knowledge of the physical 2.6 63 connections and/or cause-effect relationships between the Condensate System and the following systems: MFW.

(CFR: 41.2 to 41.9 / 45.7 to 45.8)

ES-401 10 Form ES-401-2 068 (SF9 LRS) Liquid Radwaste 04 A2.04 - Ability to (a) predict the impacts of the 3.3 64 following malfunctions or operations on the Liquid Radwaste System; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Failure of automatic isolation.

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 071 (SF9 WGS) Waste Gas Disposal 072 (SF7 ARM) Area Radiation 01 K3.01 - Knowledge of the effect that a loss or 3.2 65 Monitoring malfunction of the ARM system will have on the following: Containment ventilation isolation.

(CFR: 41.7 / 45.6) 075 (SF8 CW) Circulating Water 079 (SF8 SAS**) Station Air 086 Fire Protection 050 (SF 9 CRV*) Control Room Ventilation K/A Category Point Totals: 1 1 1 1 1 1 1 1 0 1 1 Group Point Total: 10

ES-401 11 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Emergency and Abnormal Plant EvolutionsTier 1/Group 1 (SRO)

E/APE # / Name / Safety Function K1 K2 K3 A1 A2 G* K/A Topic(s) IR #

000007 (EPE 7; BW E02&E10; CE E02)

Reactor Trip, Stabilization, Recovery / 1 000008 (APE 8) Pressurizer Vapor Space Accident / 3 000009 (EPE 9) Small Break LOCA / 3 000011 (EPE 11) Large Break LOCA / 3 AA2.10 - Ability to determine and interpret the 000015 (APE 15) Reactor Coolant Pump 10 following as they apply to the Reactor Coolant 3.7 76 Malfunctions / 4 Pump Malfunctions (Loss of RC Flow): When to secure RCPs on loss of cooling or seal injection.

(CFR 43.5 / 45.13) 000022 (APE 22) Loss of Reactor Coolant Makeup / 2 000025 (APE 25) Loss of Residual Heat Removal System / 4 G2.1.20 - Ability to interpret and execute procedure 000026 (APE 26) Loss of Component 01. steps 4.6 77 Cooling Water / 8 20 (CFR: 41.10 / 43.5 / 45.12) 000027 (APE 27) Pressurizer Pressure Control System Malfunction / 3 000029 (EPE 29) Anticipated Transient Without Scram / 1 EA2.08 - Ability to determine or interpret the 000038 (EPE 38) Steam Generator Tube 08 following as they apply to a SGTR: Viable 4.4 78 Rupture / 3 alternatives for placing plant in safe condition when condenser is not available.

(CFR: 43.5 / 45.13) 000040 (APE 40; BW E05; CE E05; W E12)

Steam Line RuptureExcessive Heat Transfer / 4 000054 (APE 54; CE E06) Loss of Main Feedwater /4 000055 (EPE 55) Station Blackout / 6 000056 (APE 56) Loss of Offsite Power / 6 000057 (APE 57) Loss of Vital AC Instrument Bus / 6 000058 (APE 58) Loss of DC Power / 6 G2.4.8 - Knowledge of how abnormal operating 000062 (APE 62) Loss of Nuclear Service 04. procedures are used in conjunction with EOPs. 4.5 79 Water / 4 08 (CFR: 41.10 / 43.5 / 45.13)

G2.4.31 - Knowledge of annunciator alarms, 000065 (APE 65) Loss of Instrument Air / 8 04. indications, or response procedures. 4.1 80 31 (CFR: 41.10 / 45.3)

AA2.05 - Ability to determine and interpret the 000077 (APE 77) Generator Voltage and 05 following as they apply to Generator Voltage and 3.8 81 Electric Grid Disturbances / 6 Electric Grid Disturbances: Operational status of offsite circuit.

(CFR: 41.5 and 43.5 / 45.5, 45.7, and 45.8)

(W E04) LOCA Outside Containment / 3 (W E11) Loss of Emergency Coolant Recirculation / 4

ES-401 12 Form ES-401-2 (BW E04; W E05) Inadequate Heat TransferLoss of Secondary Heat Sink / 4 K/A Category Totals: 3 3 Group Point Total: 6

ES-401 13 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Emergency and Abnormal Plant EvolutionsTier 1/Group 2 (SRO)

E/APE # / Name / Safety Function K1 K2 K3 A1 A2 G* K/A Topic(s) IR #

000001 (APE 1) Continuous Rod Withdrawal / 1 03 AA2.03 - Ability to determine and 4.8 82 interpret the following as they apply to the Continuous Rod Withdrawal: Proper actions to be taken if automatic safety functions have not taken place.

(CFR: 43.5 / 45.13) 000003 (APE 3) Dropped Control Rod / 1 000005 (APE 5) Inoperable/Stuck Control Rod / 1 000024 (APE 24) Emergency Boration / 1 000028 (APE 28) Pressurizer (PZR) Level Control Malfunction / 2 000032 (APE 32) Loss of Source Range Nuclear Instrumentation / 7 000033 (APE 33) Loss of Intermediate Range Nuclear 08 AA2.08 - Ability to determine and 3.4 83 Instrumentation / 7 interpret the following as they apply to the Loss of Intermediate Range Nuclear Instrumentation:

Intermediate range channel operability.

(CFR: 43.5 / 45.13) 000036 (APE 36; BW/A08) Fuel-Handling Incidents / 8 000037 (APE 37) Steam Generator Tube Leak / 3 000051 (APE 51) Loss of Condenser Vacuum / 4 000059 (APE 59) Accidental Liquid Radwaste Release / 9 000060 (APE 60) Accidental Gaseous Radwaste Release / 9 000061 (APE 61) Area Radiation Monitoring System Alarms

/7 000067 (APE 67) Plant Fire On Site / 8 13 AA2.13 - Ability to determine and 4.4 84 interpret the following as they apply to the Plant Fire on Site:

Need for emergency plant shutdown.

(CFR: 43.5 / 45.13) 000068 (APE 68; BW A06) Control Room Evacuation / 8 000069 (APE 69; W E14) Loss of Containment Integrity / 5 000074 (EPE 74; W E06 & E07) Inadequate Core Cooling / 04. G2.4.21 - Knowledge of the 4.6 85 4 21 parameters and logic used to assess the status of safety functions, such as reactivity control, core cooling and heat removal, reactor coolant system integrity, containment conditions, radioactivity release control, etc..

(CFR: 41.7 / 43.5 / 45.12) 000076 (APE 76) High Reactor Coolant Activity / 9 000078 (APE 78*) RCS Leak / 3 (W E01 & E02) Rediagnosis & SI Termination / 3 (W E13) Steam Generator Overpressure / 4 (W E15) Containment Flooding / 5 (W E16) High Containment Radiation /9 (BW A01) Plant Runback / 1 (BW A02 & A03) Loss of NNI-X/Y/7 (BW A04) Turbine Trip / 4

ES-401 14 Form ES-401-2 (BW A05) Emergency Diesel Actuation / 6 (BW A07) Flooding / 8 (BW E03) Inadequate Subcooling Margin / 4 (BW E08; W E03) LOCA CooldownDepressurization / 4 (BW E09; CE A13**; W E09 & E10) Natural Circulation/4 (BW E13 & E14) EOP Rules and Enclosures (CE A11**; W E08) RCS OvercoolingPressurized Thermal Shock / 4 (CE A16) Excess RCS Leakage / 2 (CE E09) Functional Recovery (CE E13*) Loss of Forced Circulation/LOOP/Blackout / 4 K/A Category Point Totals: 3 1 Group Point Total: 4

ES-401 15 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Plant SystemsTier 2/Group 1 (SRO)

System # / Name K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G* K/A Topic(s) IR #

G2.1.32 - Ability to explain and apply system 003 (SF4P RCP) Reactor Coolant 01. limits and precautions. 4.0 86 Pump 32 (CFR: 41.10 / 43.2 / 45.12) 004 (SF1; SF2 CVCS) Chemical and Volume Control 005 (SF4P RHR) Residual Heat Removal G2.4.30 - Knowledge of events related to 006 (SF2; SF3 ECCS) Emergency 04. system operation/status that must be 4.1 87 Core Cooling 30 reported to internal organizations or external agencies, such as the State, the NRC, or the transmission system operator.

(CFR: 41.10 / 43.5 / 45.11)

A2.02 - Ability to (a) predict the impacts of 007 (SF5 PRTS) Pressurizer 02 the following malfunctions or operations on 3.2 88 Relief/Quench Tank the PRTS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Abnormal pressure in the PRT.

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 008 (SF8 CCW) Component Cooling Water 010 (SF3 PZR PCS) Pressurizer Pressure Control 012 (SF7 RPS) Reactor Protection A2.06 - Ability to (a) predict the impacts of 013 (SF2 ESFAS) Engineered 06 the following malfunctions or operations on 4.0 89 Safety Features Actuation the ESFAS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Inadvertent ESFAS actuation.

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 022 (SF5 CCS) Containment Cooling 025 (SF5 ICE) Ice Condenser 026 (SF5 CSS) Containment Spray 039 (SF4S MSS) Main and Reheat Steam 059 (SF4S MFW) Main Feedwater 061 (SF4S AFW)

Auxiliary/Emergency Feedwater 062 (SF6 ED AC) AC Electrical Distribution 063 (SF6 ED DC) DC Electrical Distribution G2.2.37 - Ability to determine operability 064 (SF6 EDG) Emergency Diesel 02. and/or availability of safety related 4.6 90 Generator 37 equipment.

(CFR: 41.7 / 43.5 / 45.12) 073 (SF7 PRM) Process Radiation Monitoring

ES-401 16 Form ES-401-2 076 (SF4S SW) Service Water 078 (SF8 IAS) Instrument Air 103 (SF5 CNT) Containment 053 (SF1; SF4P ICS*) Integrated Control K/A Category Point Totals: 2 3 Group Point Total: 5

ES-401 17 Form ES-401-2 ES-401 PWR Examination Outline Form ES-401-2 Plant SystemsTier 2/Group 2 (SRO)

System # / Name K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G* K/A Topic(s) IR #

001 (SF1 CRDS) Control Rod Drive 002 (SF2; SF4P RCS) Reactor Coolant 011 (SF2 PZR LCS) Pressurizer Level Control 014 (SF1 RPI) Rod Position 04 A2.04 - Ability to (a) predict the impacts of the 3.9 91 Indication following malfunctions or operations on the RPIS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Misaligned rod.

(CFR: 41.5 / 43.5 / 45.3 / 45.13) 015 (SF7 NI) Nuclear Instrumentation 016 (SF7 NNI) Nonnuclear Instrumentation 017 (SF7 ITM) In-Core Temperature Monitor 027 (SF5 CIRS) Containment Iodine Removal 028 (SF5 HRPS) Hydrogen Recombiner and Purge Control 029 (SF8 CPS) Containment Purge 01. G2.1.23 - Ability to perform specific system 4.4 92 23 and integrated plant procedures during all modes of plant operation.

(CFR: 41.10 / 43.5 / 45.2 / 45.6) 033 (SF8 SFPCS) Spent Fuel Pool Cooling 034 (SF8 FHS) Fuel-Handling 01 K4.01 - Knowledge of design feature(s) and/or 3.4 93 Equipment interlock(s) which provide for the following:

Fuel protection from binding and dropping.

(CFR: 41.7) 035 (SF 4P SG) Steam Generator 041 (SF4S SDS) Steam Dump/Turbine Bypass Control 045 (SF 4S MTG) Main Turbine Generator 055 (SF4S CARS) Condenser Air Removal 056 (SF4S CDS) Condensate 068 (SF9 LRS) Liquid Radwaste 071 (SF9 WGS) Waste Gas Disposal 072 (SF7 ARM) Area Radiation Monitoring 075 (SF8 CW) Circulating Water 079 (SF8 SAS**) Station Air 086 Fire Protection 050 (SF 9 CRV*) Control Room Ventilation K/A Category Point Totals: 0 0 0 1 0 0 0 1 0 0 1 Group Point Total: 3

ES-401 Generic Knowledge and Abilities Outline (Tier 3) Form ES-401-3 Facility: Ginna Nuclear Power Plant Date of Exam: October 5 - 29, 2020 Category K/A # Topic RO SRO-only IR # IR #

G2.1.1 - Knowledge of conduct of operations 2.1.1 3.8 66 requirements.

(CFR: 41.10 / 45.13)

G2.1.26 - Knowledge of industrial safety procedures 2.1.26 3.4 67 (such as rotating equipment, electrical, high temperature, high pressure, caustic, chlorine, oxygen and hydrogen.

(CFR: 41.10 / 45.12)

1. Conduct of G2.1.29 - Knowledge of how to conduct system lineups, Operations 2.1.29 4.1 68 such as valves, breakers, switches, etc..

(CFR: 41.10 / 45.1 / 45.12)

G2.1.37 - Knowledge of procedures, guidelines, or 2.1.37 4.6 94 limitations associated with reactivity management.

(CFR: 41.1 / 43.6 / 45.6)

G2.1.41 - Knowledge of the refueling process.

2.1.41 3.7 95 (CFR: 41.2 / 41.10 / 43.6 / 45.13)

Subtotal 3 2 G2.2.13 - Knowledge of tagging and clearance 2.2.13 4.1 69 procedures.

(CFR: 41.10 / 45.13)

G2.2.14 - Knowledge of the process for controlling 2.2.14 3.9 70 equipment configuration or status.

(CFR: 41.10 / 43.3 / 45.13)

G2.2.43 - Knowledge of the process used to track 2.2.43 3.0 71

2. Equipment inoperable alarms.

Control (CFR: 41.10 / 43.5 / 45.13)

G2.2.5 - Knowledge of the process for making design or 2.2.5 3.2 96 operating changes to the facility .

(CFR: 41.10 / 43.3 / 45.13)

G2.2.21 - Knowledge of pre- and post-maintenance 2.2.21 4.1 97 operability requirements.

(CFR: 41.10 / 43.2)

Subtotal 3 2 G2.3.14 - Knowledge of radiation or contamination 2.3.14 3.4 72 hazards that may arise during normal, abnormal, or emergency conditions or activities.

(CFR: 41.12 / 43.4 / 45.10)

G2.3.15 - Knowledge of radiation monitoring systems, 2.3.15 2.9 73 such as fixed radiation monitors and alarms, portable survey instruments, personnel monitoring equipment,

3. Radiation etc.

Control (CFR: 41.12 / 43.4 / 45.9)

G2.3.13 - Knowledge of radiological safety procedures 2.3.13 3.8 98 pertaining to licensed operator duties, such as response to radiation monitor alarms, containment entry requirements, fuel handling responsibilities, access to locked high-radiation areas, aligning filters, etc.

(CFR: 41.12 / 43.4 / 45.9 / 45.10)

Subtotal 2 1 G2.4.14 - Knowledge of general guidelines for EOP 2.4.14 3.8 74 usage.

4. Emergency (CFR: 41.10 / 45.13)

Procedures/Plan G2.4.43 - Knowledge of emergency communication 2.4.43 3.2 75 systems and techniques.

(CFR: 41.10 / 45.13)

ES-401 Generic Knowledge and Abilities Outline (Tier 3) Form ES-401-3 G2.4.22 - Knowledge of the bases for prioritizing safety 2.4.22 4.4 99 functions during abnormal/emergency operations.

(CFR: 41.7 / 41.10 / 43.5 / 45.12)

G2.4.40 - Knowledge of SRO responsibilities in 2.4.40 4.5 100 emergency plan implementation.

(CFR: 41.10 / 43.5 / 45.11)

Subtotal 2 2 Tier 3 Point Total 10 7

v t e Letter Sequence Other
CAC:000500, (Open)
Initiation Acceptance... Administration Questions Answers Results Approval... Other: ML20055D883, ML20055E009, ML20057E559, ML20057E560, ML20087G852, ML20087H514, ML20184A247, ML20184A248, ML20240A318, ML20240A322, ML20254A128, ML20254A272, ML20268A322, ML20268B437, ML20268C197, ML20274A136, ML20279A331, ML20297A306, ML20300A556, ML20301A632, ML20302A234, ML20302A235, ML20303A011, ML20303A016, ML20307A010, ML20307A019, ML20321A279, ML20322A350, ML20323A018, ML20325A031, ML20328A162, ML20329A432, ML20329A442, ML20350B716, ML20350B723, ML20350B739, ML20350B785, ML21012A270, ML21025A073, ML21025A143, ML21025A403, ML21025A405, ML21025A414, ML21040A471, ML21040A483, ML21043A207, ML21050A084, ML21050A119, ML21050A227, ML21056A220... further results
MONTHYEAR2020-03-12 [Table View]

ML20328A162

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